ML120480088

Initial Exam 2011-302 Final Sim/In-Plant JPMs

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Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01000110605 Task

Title:

Withdrawing Control Rod Shutdown JPM No.: 2011-2 NRC JPM A Bank B K/A

Reference:

003 AK3.04 3.8/4.1 Examinee: NRC Examiner: N/A Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Preparations for a reactor startup are in progress.

GP-003 has been completed up to Step 8.2.22.d.

Reactor Engineering has provided Mode 2 determination point of 28 steps on Control Bank C.

You are the Reactor Operator.

Task Standard: Drive Control Rods into the core to ensure reactor is shutdown.

Required Materials: GP-003, Normal Plant Startup from Hot Shutdown to Critical, Revision 94 AOP-001, Malfunction of Reactor Control System, Revision 26 General

References:

GP-003 AOP-001 2011-2 NRC JPM A NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Handouts: GP-003 completed up to Step 8.2.22.d Initiating Cue: The CRS has directed you to continue rod withdrawal in support of performing a reactor startup, starting at Step # 8.2.22.d.

Time Critical Task: NO Validation Time: 7 minutes SIMULATOR SETUP

1. Reset to IC-806

2. Open SCN: 008_JPM_NRC_A

3. Place simulator in run when directed by the examiner.

2011-2 NRC JPM A NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 10 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk START TIME:

• Performance Step: I Select SBB on the Rod Bank Selector switch (Step 8.2.22.d)

Standard: Candidate places the rod bank selector switch in the SBB (Shutdown Bank B) position.

Examiners Note:

Comment:

NOTE During rod withdrawal, the Operator At The Controls (OAC) is manipulating the Rod Withdrawal and monitoring applicable parameters. Simultaneously, a licensed RO other that the assigned OAC will assist in performing the Attachment 10.3, Control Rod Withdrawal Checklist.

CAUTION When above 220 steps withdrawn, Shutdown Banks should be withdrawn in i or 2 step increments to prevent overstepping of the control rods.

2011-2 NRC JPMA NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 10 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 2 Withdraw Shutdown Bank B to 225 steps while performing the checks of Attachment 10.3, Control Rod Withdrawal Checklist.

(Step 8.2.22.e)

Standard: Candidate places the IN-HOLD-OUT lever in the OUT position and withdraws Shutdown Bank B rods.

Examiners Note: When the rods reach 70 steps withdrawn, 4 of the rods will drop into the core. The candidate will be expected to perform the immediate actions of AOP-00i and then enter the procedure.

Examiners Cue:

Corn ment:

NOTE Steps I through 3 are immediate action steps.

Performance Step: 3 Check unexpected rod motion IN PROGRESS (Step 1)

Standard: Candidate determines that no unexpected rod motion is in progress, proceeds to the RNO step and proceeds to Step 7.

Examiners Note:

Corn ment:

2011-2 NRC JPMA NUREG 1021, Revision 9, Supplement I

Appendix C Page 5 of 10 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 4 Make a PA announcement for procedure entry (Step 7)

Standard: Candidate uses an available PA handset and makes a PA announcement for entry into AOP-001.

Examiners Note:

Comment:

Performance Step: 5 Determine if multiple rods have dropped as follows: (Step 8)

a. Analyze indications for multiple rod drop

• Prompt drop PRESENT

• More than 1 rod bottom light ILLUMINATED

• More than i IRPI INDICATES ON BOTTOM

b. Check multiple dropped rods - PRESENT Standard: Candidate determines that there are multiple dropped rods by the IRPI indication for the affected rods at zero and rod bottom bistables illuminated.

Examiners Note:

Comment:

2011-2 NRC JPM A NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 10 Form ES-C-I PERFORMANCE INFORMATION Performance Step: 6 Check reactor status MODE 1 OR 2 (Step 9)

Standard: Candidate determines the reactor is in Mode 3, proceeds to the RNO step and proceeds to Section A, Dropped Rod.

Examiners Note:

Comment:

Performance Step: 7 Check plant status Mode 1 (Step 1, Section A)

Standard: Candidate determines the reactor is in Mode 3, proceeds to the RNO step and proceeds to caution prior to Step 35.

Examiners Note:

Comment:

CAUTION Attempts to recover a dropped rod from a Mode 2 initial condition could result in an inadvertent return to criticality.

2011-2 NRC JPMA NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 10 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 8 Check plant status MODE 2 (Step 35, Section A)

Standard: Candidate determines that the plant is in Mode 3 and proceeds to the RNO step which directs transition to Step 37.

Examiners Note:

Comment:

• Performance Step: 9 Perform the following: (Step 37, Section A)

a. Fully insert all Control Bank rods

b. Fully insert Shutdown Bank B rods

c. Fully insert Shutdown Bank A rods Standard:

Candidate determines that the control bank rods are fully inserted by observing the IRPI and step counters for the control bank rods.

Candidate starts inserting Shutdown Bank B rods by placing the IN-HOLD-OUT lever in the IN position and observes the IRPI downward movement along with the applicable step counters indicating inward rod motion.

Examiners Note: Once the rod insertion of Shutdown Bank B has commenced, the JPM can be terminated.

Comment:

2011-2 NRC JPM A NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 10 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: When control rod insertion is commenced, the evaluation of this JPM is complete.

STOP TIME:

2011-2 NRC JPM A NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 10 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM A Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPMA NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 10 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: Preparations for a reactor startup are in progress.

GP-003 has been completed up to Step 8.2.22.d.

Reactor Engineering has provided Mode 2 determination point of 28 steps on Control Bank C.

You are the Reactor Operator.

INITIATING CUE: The CRS has directed you to continue rod withdrawal in support of performing a reactor startup, starting at Step # 8.2.22.d.

2011-2 NRC JPM A NUREG 1021 Revision 9, Supplement 1

Appendix C Page 10 of 10 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: Preparations for a reactor startup are in progress.

GP-003 has been completed up to Step 8.2.22.d.

Reactor Engineering has provided Mode 2 determination point of 28 steps on Control Bank C.

You are the Reactor Operator.

INITIATING CUE: The CRS has directed you to continue rod withdrawal in support of performing a reactor startup, starting at Step # 8.2.22.d.

2011-2 NRC JPM A NUREG 1021, Revision 9, Supplement 1

Progress Energy Connuous H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 3 PART3 GP-003 NORMAL PLANT STARTUP FROM HOT SHUTDOWN TO CRITICAL REVISION 94 CAUTION Reactor Startup is a Major Reactivity Manipulation (RI) as defined by OPS-NGGC-I 306, Reactivity Management Program GP-003 Rev. 94 Page 1 of 60

SUMMARY

OF CHANGES PRR 465999 GP-003 Revision 94 Step I Section REVISION COMMENTS 5.4.7 Added or EOP-E-O after PATH-I in second bullet. (PRR 465999)

GP-OO3 Rev. 94 Page 2 of 60

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE .4

2.0 REFERENCES

4 3.0 RESPONSIBILITIES 8 4.0 PREREQUISITES 8 5.0 PRECAUTIONS AND LIMITATIONS 9 6.0 SPECIAL TOOLS AND EQUIPMENT 14 7.0 ACCEPTANCE CRITERIA 14 8.0 INSTRUCTIONS 15 8.1 Initial Conditions 15 8.2 Instructions for Taking the Reactor Critical 26 8.3 Critical Operations 46 8.4 Post Critical Operations 48 9.0 RECORDS 50 10.0 ATTACHMENTS 50 10.1 ESTIMATED CRITICAL CONDITION FORM 51 10.2 INVERSE COUNT RATE RATIO (1IM) DATAAND PLOT FORM 57 10.3 CONTROL ROD WITHDRAWAL CHECKLIST 60 GP-003 I Rev. 94 I Page 3 of 60

1.0 PURPOSE To provide the initial conditions, precautions, and instructions for a safe, normal Plant startup from MODE 3 to MODE 2.

RI REACTIVITY EVOLUTION

2.0 REFERENCES

2.1. NRC, INPO and Industry Documents

1. SOER 88-02, Premature Criticality Events During Reactor Startup

2. SOER 90-3, Nuclear Instrument Miscalibration (Recommendation 2)

3. SOER 03-2 Recommendation 4.b, Managing Core Design Changes

4. Westinghouse Recommendation, Standard Information Package on Chemistry, Criteria & Specification SIP 5-1, Table 1.5 Note B

5. SOER 07-1, Reactivity Management, Recommendation #1, Standards and Expectations

6. SOER 07-1, Reactivity Management, Recommendation #2, Crew Supervision

7. SOER 07-1, Reactivity Management, Recommendation #3, Reactor Engineering

8. SOER 98-1, Safety System Status Control (Recommendation 2A)

(CR 98-01853)

9. SOER 96-1, Control Room Supervision, Operational Decision Making, and Teamwork. (Recommendations I & 2)

10. SOER 96-02, Design and Operating Considerations for Reactor Cores (Recommendation 1)

11. EPRI PWR Primary Water Chemistry Guidelines, Volume 1, Revision 5 GP-003 Rev. 94 Page 4 of 60

2.2. NGG Procedures and Documents

1. OPS-NGGC-1 000, Fleet Conduct of Operations

2. OPS-NGGC-1 305, Operability Determinations

3. OPS-NGGC-1 306, Reactivity Management Program

4. CAP-NGGC-0200, Condition Identification and Screening Process

5. NFP-NGGC-0029, Reactivity Manipulation Plan Development

6. EGR-NGGC-1 020, Conduct of Reactor Engineering and Nuclear Fuels Management 2.3. RNP Procedures and Documents

1. Improved Technical Specifications (ITS)

2. Station Curve Book

3. Emergency Operating Procedure Network

4. AOP-001, Malfunction of Reactor Control System

5. GP-002, Cold Shutdown to Hot Subcritical at No Load T-AVG

6. GP-004, Post Trip Stabilization

7. GP-006-1, Normal Plant Shutdown From Power Operation to Hot Shutdown

8. GP-006-2, Rapid Plant Shutdown

9. OP-002, Nuclear Instrumentation System

10. OP301, Chemical and Volume Control System

11. OP-405, Main and Extraction Steam System

12. OP-406, Steam Generator Blowdown/Wet Layup System

13. OP-603, Electrical Distribution

14. OP-923, Containment Integrity

15. OST-001, Nuclear Instrumentation Source Range, Intermediate Range, Power Range GP-003 Rev. 94 Page 5 of 60

2.3 (Continued)

16. OST-008, Nuclear Instrumentation Startup Rate Channel

17. OST-011, Rod Cluster Control Exercise & Rod Position Indication Monthly Interval

18. OST-020, Shiftly Surveillances

19. OST-021, Daily Surveillances

20. OST-022, Weekly Surveillances

21. OST-023, Monthly Surveillances

22. OST-051, Reactor Coolant System Leakage Evaluation

23. OST-052, RCS Leakage Test and Examination Prior to Startup Following Opening of the Primary System

24. OST-160, Pressure Isolation Check Valve Back Leakage

25. OST-901, HVH Condensate Measuring System

26. OST-920, Operations Cold Shutdown Test Procedure

27. MST-010, Source Range Trip Logic Train A and B

28. MST-011, Reactor Protection Logic Train A and B at 0 Power

29. MST-551, Turbine Trip Logic Channel Testing

30. MST-932, Low Autostop Oil Pressure and Turbine Stop Valve Closure Testing

31. EST-032, Visual Inspection of Hydraulic Mechanical Shock Suppressors

32. EST-033, Functional Testing of Hydraulic and Mechanical Shock Suppressors

33. EST-050, Refueling Startup Procedure

34. CP-001, Chemistry Monitoring Program

35. OMM-001-12, Minimum Equipment List and Shift Relief

36. OMM-001-6, Operations Assessments

37. FMP-001, Core Operating Limits Report (COLR)

GP-003 Rev. 94 Page 6 of 60

2.3 (Continued)

38. FMP-012, Manual Determination of Shutdown margin Boron Concentration

39. EMP-1715(P), POWERTRAX Users Guide

40. PLP-006, Containment Vessel Inspection/Closeout

41. PLP-037, Conduct of Infrequently Performed Tests or Evolutions and Pre-Job Briefs

42. PLP-100, Technical Requirements Manual (TRM)

43. Project 97-00161, IN 96-69 Operator Actions Affecting Reactivity

44. EC 47208, NR-45 Recorder Replacement

45. LER-2004-002-00, Entry into Mode 3 With the SDAFW Pump inoperable

46. FMP-025, POWERTRAX, OSG, ECC, SDB & PDD Modules

47. APP-005, NIS & Reactor Control

48. APP-036, Auxiliary Annunciator

49. APP-004, First Out Reactor Trips

50. OMM-022, Emergency Operating Procedures Users Guide

51. OMM-024, Rod Position Channel Check

52. EC 72149, RNP Cycle 27 Reload Design and Safety Analyses 2.4. Nuclear Condition Reports (NCRs) and Adverse Condition Reports (ACRs)

1. ACR 94-01276, Steam Line Drains Found Out of Position

2. ACR 94-01746, PWST Curve Inadequacy

3. ACR 94-01088, Spray Additive Tank Curve Inadequacy

4. CR 96-02954, SOER 96-01 RESPONSE.

5. NCR 233326, Enhance NARPI Adjustment Guidance in AOP-1 and GPs

6. NCR 308587, GP-003 Requirement for OST-001 Performance

7. NCR 358896, PIC-497 Setpoint Not Updated in OAO Logs

8. IMPR 364913, NCON Assignment Tracking

9. NCR 433838, GP-003 Actions Directed by Note GP-003 Rev. 94 Page 7 of 60

3.0 RESPONSIBILITIES

1. Operations is responsible for the performance, review, and approval of this procedure.

2. Reactor Engineering is responsible for providing support in the Control Room during the startup process as defined in OPS-NGGC-1306, Reactivity Management Program and EGR NGGC-1020, Conduct of Reactor Engineering and Nuclear Fuels Management.

INIT 4.0 PREREQUISITES

1. IF a heatup from MODE 4 to MODE 3 has been performed, THEN VERIFY GP-002, Cold Shutdown to Hot Subcritical at No Load T-AVG, is complete.

2. IF this startup is preceded by a Reactor Shutdown, THEN VERIFY GP-006-1, Normal Plant Shutdown from Power Operation to Hot Shutdown, or GP-006-2, Rapid Plant Shutdown, is complete.

3. IF this startup follows a Reactor trip, THEN VERIFY GP-004, Post Trip Stabilization, is complete.

4. VERIFY that an approved Reactivity Manipulation Plan for this startup is available as required by OPS-NGGC-1 306, Reactivity Management Program.

5. VERIFY the Control Room access doors are posted to limit access lAW OPS-NGGC-1 000, Fleet Conduct of Operations, and OPS-NGGC-1 306, Reactivity Management Program.

GP-003 Rev. 94 Page 8 of 60

5.0 PRECAUTIONS AND LIMITATIONS 5.1. Control Rod Banks:

1. Control rod banks shall always be withdrawn and inserted in the prescribed sequence: (ITS LCO 3.1.6)

• Withdrawal sequence is Control Bank A, Control Bank B, Control Bank C, and Control Bank D.

• Insertion sequence is Control Bank D, Control Bank C, Control Bank B, and Control Bank A.

2. When automatic bank sequencing is used (Rod Bank Selector switch in A or M), verify correct bank sequencing by monitoring both the group step counters AND the rod position indicators.

3. Overlap of consecutive control banks shall not exceed 97 steps. For example, when Bank C is 128 steps withdrawn, withdrawal of Bank D will begin, with Banks C and D moving together until C is fully withdrawn, and D is 97 steps withdrawn. (ITS LCO 3.1.6)

4. When withdrawing control rods in MODES 1 and 2, efforts should be made to maintain RPI within the ITS alignment limits. Rod motion should be stopped AND adjustments made, as allowed, to maintain indication within the limits. (ITS LCO 3.1.7/LCO 3.1.4) f GP-003 Rev. 94 Page 9 of 60

5.2. Shutdown Bank Rods:

ITS LCO 3.1.5 requires that the Shutdown Bank Rods be within insertion limitations specified in the COLR during MODE I and MODE 2 with any Control Bank not fully inserted. The COLR requires that the Shutdown Bank Rods be withdrawn to at least 225 steps.

NOTES: The COLR identifies the required Shutdown Margin (SDM) based on plant conditions, which include:

1) Whether the rod control system is capable of rod withdrawal

2) The number of RCPs in operation

3) The RCS temperature to be maintained.

The required Boron Concentration can be determined using Powertrax or the Station Curve Book using the SDM identified in the COLR.

2. The following constraints are placed on Shutdown Bank and Control Bank Rod positioning when in MODES 3, 4 and 5:

a. All Control Rods including Shutdown Banks A and B are fully inserted. The Reactor Trip Breakers may be left closed as long as the Shutdown Margin (SDM) requirements of the Core Operating Limits Report (COLR, FMP-001) are fully met.

b. Primary plant heat-up and cooldown with the Reactor Trip Breakers shut (RCCA Control Rod Drive Mechanisms energized) requires that all Shutdown and Control Rods are stepped out to the 5 step point.

This is to help prevent thermal binding of the RCCA rodlets in the individual dashpots.

3. The RCS shall be borated as conditions require AND the concentration confirmed by sampling.

5.3. Precautions during Approach to Criticality:

1. Startup Rate shall NOT be permitted to exceed 1.0 decade/minute as read on the STARTUP RATE METER.

2. An Inverse Count Rate Ratio Plot (1/M) with a minimum of four data points (including baseline data point which is taken after Shutdown Banks A and B are fully withdrawn) shall accompany the Reactor startup.

3. After the third doubling, if the predicted critical rod position from the 1/M plot falls outside the +/-500 pcm position, the Reactor Operator should notify the SM and Reactor Engineer for further guidance.

(Project 97-00161)

GP-003 Rev. 94 Page 10 of 60

5.4. General

1. OPS-NGGC-1306, Reactivity Management Program, defines a reactor startup as a Major Reactivity Manipulation (RI). The Reactivity management requirements of OPS-NGGC-1 306 should be reviewed prior to commencing the plant start-up AND periodically during the evolution to ensure proper compliance.

2. Reactor Startup shall be secured if all RPIs are NOT operable. Reactor startup will NOT be commenced without an approved alternate means of verifying Control Rod position.

3. Criticality shall be anticipated at any time when the Shutdown Banks or Control Banks are being withdrawn, OR when boron dilution operations are in progress.

4. If the count rate on either Source Range channel goes up by a factor of two or more during any step involving a boron concentration change, the operation shall be stopped immediately AND suspended until a satisfactory evaluation of the situation has been made.

5. When the Reactor is subcritical, positive reactivity shall NOT be added by more than one method at a time. (Exception: Due to the slow insertion rate contributed by the decay of Xenon, positive reactivity addition by the Operator may be performed during periods of Xenon decay.) (SOER 07-1, Recommendation #1)

6. The Reactor will NOT be made critical until the Hydrogen concentration in the RCS is between 25 and 50 cc/kg of water. (EPRI PWR Primary Water Chemistry Guidelines, Volume 1, Revision 5)

GP-003 Rev. 94 Page 11 of 60

5.4 (Continued)

7. The following requirements apply to the Source Range Nuclear Instruments when in MODE 2 below P-6: (ITS Table 3.3.1-1 item 4)

IF one Source Range channel becomes inoperable, THEN immediately suspend operations involving positive reactivity additions. Also reference ITS 3.3.1, Required Action 1.1 and the ITS basis for clarification concerning allowances for limited RCS boron and RCS temperature changes.

IF two Source Range channels become inoperable, THEN immediately trip the Reactor AND GO TO PATH-i or EOP-E-O IF any of the following conditions are met: (Reference to ITS 3.3.1, Table 3.3.1-1 Item 4 and AP P-005)

The plant is in MODE 2 with Reactor Power less than the P-6 set point The plant is in MODE 3 with the Rod Control System capable of rod withdrawal The plant is in MODE 3 with one or more rods NOT fully inserted

8. Whenever possible, the Steam Dump Valves should be used for RCS temperature control.

9. Feedwater additions during Hot Shutdown should be initiated as slowly as possible AND should NOT exceed 400 gpm OR 0.2 X 106 Ibm/hr to minimize the thermal stress cycles on the feedwater nozzle.

10. During Secondary Plant warm up, steam should be drawn off slowly and feedwater additions should be regulated to maintain the desired temperature range of the RCS.

GP-003 Rev. 94 Page 12 of 60

5.4 (Continued)

11. ITS Table 1.1-1 defines MODE 2 as KEFF greater than or equal to 0.99 and Rated Thermal Power (RTP) less than or equal to 5%

(excluding decay heat). Since KEFF indication is not available, the following is used to define when MODE 2 is entered in this procedure:

When a second bank of rods (control or shutdown) is withdrawn more than 20 steps OR when the RCS boron concentration is less than the lowest boron concentration required for Shutdown Margin by POWERTRAX or by Curve 1.11 (Curve Book) for the current core burnup and RCS temperature, the Reactor shall be considered to be in MODE 2.

The above description of MODE 2 may be modified by an approved reactivity balance for the current or proposed plant conditions which shows the KEFF for the plant condition in question such that the new MODE 2 declaration point is determined.

12. If criticality occurs with the Control Rods BELOW the Minimum Control Rod Insertion Limit, the Reactor should be shut down in a controlled manner and the Reactor Engineer notified of the reactivity anomaly. (ITS LCO 3.1.6)

13. The minimum RCS temperature for criticality is 530°F (ITS LCO 3.4.2)

14. The POWERTRAX Estimated Critical Condition (ECC) is the official estimate. The GP-003 ECP hand calculation is a back-up. Deviations of 250 pcm or more between the two should be investigated. If the deviation exceeds 500 pcm, do not attempt to take the reactor critical until the deviation is resolved. (SOER 07-1, Recommendation 3; FMP-025)

15. Auxiliary Boilers A and B are rated at 300 Horse Power (HP),

approximately 10,350 lbs/Hr steam production each. Auxiliary Boiler C is rated at 600 HP, approximately 23,000 lbs/Hr steam production. It is normal to run two Auxiliary Boilers. Depending on the wear condition of the Main Turbine Gland Seals and the Auxiliary Steam (AS) System loads, it may be necessary to run all three Auxiliary Boilers to maintain stable Gland Seal pressure. Loss of Gland Seal pressure could lead to a loss of Main Condenser Vacuum. Loss of Main Condenser Vacuum would result in a loss of temperature control when using the Steam Dumps. This will complicate the reactor start-up and cause unnecessary distractions while approaching criticality.

GP-003 Rev. 94 Page 13 of 60

5.4 (Continued)

16. OPS-NGGC-1 306, Reactivity Management Program, defines a Reactivity Management Event (RME) as follows:

Any unexpected occurrence which results in a significant change in core reactivity, loss of reactivity control, operation in an unanalyzed condition, or a reduction of margin to the licensing basis.

Any indications of an RME necessitate the submittal of an NCR lAW CAP-NGGC-0200, Condition Identification and Screening Process.

Depending on the type and severity of the RME, plant shutdown may be required. Reactor restart after an RME will be conducted only after approval of the Plant Nuclear Safety Committee (PNSC).

6.0 SPECIAL TOOLS AND EQUIPMENT N/A 7.0 ACCEPTANCE CRITERIA N/A GP-003 Rev. 94 Page 14 of 60

Section 8.1 Page 1 of 11 8.0 INSTRUCTIONS INIT 8.1. Initial Conditions N E: This section has been screened lAW PLP-037 criteria and determined N/A to PLP-037.

VERIFY this revision is the latest revision available.

Date /

Performance of the steps in this section is not sequence dependent and can be performed in any order.

Documentation of the procedure completion dates and MODES is solely to assist with the decision making questions in the subsequent steps.

2. RECORD the last date performed for the following procedures:

OST-001 OST-008 fi?

OST-021 for MODE OST-022 7i14ii for MODE OST-023 for MODE OST-051 f OST-052 77 OST-160 OST-920 MST-010 MST-011 MST-551 MST-932 77d )

PLP-006, Attachmerd6.3

(

GP-003 Rev. 94 Page 15 of 60

Section 8.1 Page 2 of 11 INIT

3. IF the test frequency will be due during the startup, THEN PERFORM OST-051. (ITS SR 3.4.13.1)

) /j

4. IF OST-OO1 has not been completed in the previous 92 days, THEN PERFORM the OST-OO1.

5. IF OST-008 has not been completed in the previous 7 days, THEN PERFORM the OST-008.

6. IF OST-Oll has not been completed within the previous 31 days, THEN PERFORM the OST-Oll.

7. IF the primary system was opened, THEN VERIFY OST-052 has been performed.

N E: OST-160 is required prior to entry into MODE 2 whenever the unit has been in MODE 5 for seven days or more AND leakage testing has not been performed within the previous nine months OR within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following a PIV actuation due to automatic or manual action OR within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following flow through any RCS Ply. (ITS SR 3.4.14.1).

8. IF required, THEN VERIFY OST-160 has been performed.

9. IF this Reactor Startup is immediately following a Refueling Outage, THEN VERIFY completion of the required Refueling Test procedures in OST-920. 1

10. IF the plant has been in Cold Shutdown, THEN VERIFY completion of the required Cold Shutdown Test procedures in OST-920.

11. VERIFY one of the following (N/A the two items NOT used):

MST-011 has been performed within the previous 31 days.

MST-01 0 was completed within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of entering MODE 3 from MODE 2.

MST-01 0 was completed prior to closing the reactor trip breakers if not performed within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of entering MODE 3 from MODE 2.

GP-003 Rev. 94 Page 16 of 60

Section 8.1 Page 3 of 11 INIT

12. VERIFY that either MST-551 OR MST-932 has been performed within the previous 31 days.

J

13. REVIEW all open degraded but operable SSCs (NCONS) as follows:

CA ON Ensure all degraded or non-confor g conditions as identified in open NCON assignments have either been corrected or that startup without correction, along with any applicable compensatory actions, has been justified and the justification has been concurred with by the Plant Nuclear Safety Committee (PNSC). The justification must provide an explanation as to why the corrections could not be made during the current outage and provide an alternate, acceptable, completion date based on the safety significance. (Reference OPS-NGGC-1305 and IMPR 364913)

a. VERIFY that all degraded SSCs scheduled for correction/restoration have been restored.

b. IF degraded SSC could not be restored during this outage, THEN RECORD the following information:

Impacted SSC along with any required Expected PNSC Meeting AR compensatory actions. (COMP ACTION may be marked date for SSC Number & date Number as N/A if none is listed or required.) restoration. of concurrence.

SSC:

k 1

i/ Comp Action: Al/A SSC:

/A CompAction:

SSC:

MM Comp Action:

SSC:

/J/k /A Comp Action:

f4 iJ/A SSC:

i7A Comp Action: /sJ (7k 1

GP-003 Rev. 94 Page 17 of 60

Section 8.1 Page 4 of 11 8.1.13 (Confinued) itiiI

c. VERIFY each Compensatory Action recorded in Step 8.1.13.b is also recorded in the Robinson Nuclear Plant Operations Compensatory Action Data Base.

14. REVIEW the following documents AND VERIFY all Post-Maintenance Testing is completed OR scheduled for completion and conditions do NOT exist that would jeopardize the operability of ITS or TRM required equipment:

[LER 2004-002-00]

Temporary Equipment Modification Log Equipment Inoperable Record Caution Tag Log E The Reactor will not be made critical until the Hydrogen concentration in the RCS is between 25 and 50 cc/kg of water. (EPRI PWR Primary Water Chemistry Guidelines, Volume 1, Revision 5)

15. REQUEST E&C to sample the RCS to verify RCS Hydrogen Concentration is between 25 and 50 cc/kg of water.

2 Concentration \

H cc/kg j7/r/)

EContac (Prin name)

The S/G Blowdown Auto Closure Defeat key switches are to be operated in pairs AND are located in back of RTGB.

/L

16. PLACE the S/G Blowdown Auto Closure Defeat key switches to the NORMAL position to restore the Steam Generator Blowdown valve auto closure signal from the Main Feedwater Pump breakers.

• FW PPS OFF Train A

• FW PPS OFF Train B T

GP-.003 Rev. 94 Page 18 of 60

Section 8.1 Page 5 of 11 INIT

17. VERIFY that the RTGB AFW auto initiation status lights, TRAIN A DEFEATED and TRAIN B DEFEATED, are EXTINGUISHED.

• TRAIN A DEFEATED Extingur

• TRAIN B DEFEATED

18. VERIFY that the Nuclear Instrumentation Checklist attachment of OP-002 has been completed. i-1

19. VERIFY the Containment Evacuation Horn is operable as demonstrated by the last satisfactory performance of either OST-O01 or PLP-006, Attachment 6.

ION During MODE 3 and MODE 2, an AudTble and Visual Flux Count Rate shall be maintained. Audible Count Rate is ONLY required when Source Range Instruments are operating (i.e., in MODE 2 when Source Range Instruments are no longer in service, Audible Count Rate is NOT available).

20. VERIFY the CHANNEL SELECTOR switch on the Audio Count Rate Channel drawer is selected to SR 31 OR SR 32.

21. VERIFY the SR count rate is audible on the Audio Count Rate Channel speaker AND visible on at least one Source Range channel CPS NEUTRON LEVEL meter. KZ

22. VERIFY the following NIS AND Rod Control System recorders are in service AND operating properly:

- NR-45, POWER RANGE RECORDER (CPS, AMPS,

- NR-53, EXCORE NIS RECORDER NR-46, POWER RANGE, NI-41, Nl-43, 0-200%

NR-47, POWER RANGE, Nl-42, NI-44, 0-200%

GP-003 Rev. 94 Page 19of60

Section 8.1 Page 6 of 11 INIT

23. IF the Steam Line PORV setpoint controllers are NOT set for power operation, THEN PERFORM the following:

CAUTION The SIG PORV proportional-reset local controller will cause the PORVto lift if the output signal is 3-15 psig.

The output signal will quickly lift the PORV if setpoint is equal to or less than steam line pressure, AND therefore requires expeditious actions to raise the setpoint once an output signal is noticed to prevent PORVs from lifting.

NOTE: Steps 2 through 8 should be performed in order for each PORV setpoint AND repeated until the S/G PORVs are properly set.

The BOP Operator and Auxiliary Operator should review this task prior to setting the SIG PORV setpoints.

S/G PORV controller setpoint is indicated on the lower orange indicator on the 0-1500 psig scale.

Station an Operator at the Secondary Control Panel in communication lNlT 1

with the Control Room PIC-477 PIC-487 PIC-497 INIT NIT INIT p 2 Verify Tavg is at 547°F +1- 0.5°F (546.5°F to 547.5°F) ,J/4 J/ /J7,4 Slowly adjust the SG PORV potentiometer on the RTGB until the local 1 3 CONTROLLER AIR PRESS starts to go up as reported by the Operator at the controller.

A)14 1 9

/iIC) 4 iJ4 WHEN the local Operator sees a rising CONTROLLER AIR PRESS, THEN report the indicated controller setpoint to the Control Room. /

MII fjA /IJA f 19

/\)/4 WHEN the local Operator reports the indicated controller setpoint, THEN record the controller setpoint reported in the previous s,te.

PIC-477 indicated:

PIC-487 indicated: Ah,4 psig iI44 PIC-497 indicated:

Lower the PORV potentiometer setting until CONTROLLER AIR 6

PRESS is at minimum as reported by the local Operator.

GP-003 Rev. 94 Page 20 of 60

Section 8.1 Page 7 of 11 PIC-477 PIC-487 PIC-497 8 1 23 ( C on t flue d )

INIT NIT INIT the required PORV setpoint by adding 30 psig to the Determine pressure recorded in Stej 8.1.23.5.

PlC 477 /\J( 1 Indicated psig + 30

= ) j4 j

4 etpoint psig PlC 487 I.J(4 psig + 30 Indicated Setpoint PIC-497: psig + 30 A1/P4psig Indicated Setpoint Slowly adjust the SG PORV potentiometer to the controller setpoint 8

calculated in the previous step as reported by the local Operator.

RV-1 RV-2 RV-3 9 Log the SG PORV potentiometer settings in the columns to the right.

,,j]A ,qfI jJ/

Record the SG PORV potentiometer setting on the Status Board AND / j 10 notify the Outside AO to update the Outside AO Logs to reflect the new PORV pressure setpoints.

/J I

/4- I V js.J14 J

+.

11 Send a copy of this page to the simulator support group itk INIT

24. VERIFY the Outside Auxiliary Operator (OAO) logs and Status Board are updated for the new Main Steam PORV setpoints recorded in Step 7 of the Data Table in the previous step.

(NCR 358896)

OAO

25. IF this startup is after a Reactor Trip OR Safeguards Actuation, THEN VERIFY the Post Trip/Safeguards Review Report portion of OMM-OO1-6 has been completed as indicated by the appropriate startup approval signature.

GP-003 Rev. 94 Page 21 of 60

Section 8.1 Page 8 of 11 INIT CS Temperature Control with the Main Steam Isolation Valves (MSIVs) shut is accomplished lAW OP-405, Main Steam System, and OP-923, Containment Integrity. These procedures require a dedicated operator for operation and

/ isolation of the flow path.

RCS Temperature Control via Steam Dump Operation is set in either GP-002 or GP-004.

26. VERIFY RCS temperature is being maintained between 545°F and 549°F using one of the following (N/A the method not used):

(ACR 94-01276)

Controlling RCS Temperature section of OP-405.

Steam Dump operation in STEAM PRESS mode.

27. IF this startup is required due to a Reactor Trip, THEN VERIFY Blowdown to the Flash Tank with Heat Recovery Bypassed Section of OP-406 is completed.

N E Step 8.1.28 may be marked as Not Applicable (N/A) if this is a post-trip Reactor restart where decay heat is providing enough steam for Gland Seal System operation.

28. To minimize distractions during the Reactor startup, VERIFY the Auxiliary Boilers are maintaining the Main Turbine Gland Seal pressure with minimal Aux. Boiler Trouble alarms on APP-036, Auxiliary Annunciator Panel.

29. To minimize distractions during Reactor startup, VERIFY test(s) which require coordination with the Control Room, have been authorized by the Manager Operations, AND are documented below: (CR 96-02954, SOER 96-1, Recommendations 1 & 2, SOER 96-02, Recommendation 1, SOER 98-1, Recommendation 2A, OPS-NGGC-1 306)

,e- id/A

.JfA ti/A GP-003 Rev. 94 Page22of60

Section 8.1 Page 9 of 11 7 i.Ni]

core alteration is the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel.

30. VERIFY the following:

a. IF this startup is following a core alteration, THEN NOTIFY the Reactor Engineer to perform the prerequisites of EST-050.

ju1/i4 Reactor Engineer Contact (Print name)

b. VERIFY OMM-001-12 MODE 2 Checklist is completed.

lODE I required SRs shall be performed in the procedures listed below if the plans are to immediately continue to MODE 1 following startup.

7 Refer to the information in Step 8.1.2 when determining the need to perform OST-021, OST-022 and OST-023.

c. MODE 2 required SRs (and MODE I if required) identified in the following, are completed:

OST-020, Shiftly OST-021, Daily

d. IF the most recent performance of OST-022 and OST-023 did not include the MODE I SRs, THEN PERFORM the MODE I and MODE 2 inspections and tests:

OST-022, Weekly OST-023, Monthly

e. A Reactor Engineer is in the Control Room to support the startup (SOER 96-02).

GP-003 Rev. 94 Page 23 of 60

Section 8.1 Page 10 of 11 INIT If this Reactor Start-up is immediately following a GP-002 RCS Heat-up, the Shutdown Banks and Control Banks may have been withdrawn to 005 steps each to prevent thermal binding I

31. PERFORM the following to VERIFY both Shutdown Banks AND all of the Control Banks are all at zero steps: [CAPR 173910-07]

a. RECORD the AS FOUND Group Counter readings for each of the Shutdown Banks AND the Control Banks: 2L BANK GROUPI GROUP2 Shutdown Bank A C Shutdown Bank B 50 Control Bank A Control Bank B Control Bank C (Ye Control Bank D

b. IF ANY Group Counter is displaying any reading other than 000 OR IF there is any reason to believe that any RCCA is V not fully inserted, THEN PERFORM the following:

Unless the reason for initiating a Reactor Trip is due to an abnormal or emergency condition, entry into the Emergency Operating Procedure (EOP)

Network is NOT required when tripping the Reactor as a part this procedure.

(OMM-022)

(1) DEPRESS EITHER MANUAL REACTOR TRIP BUTTON.

(2) VERIFY the Reactor Trip Breakers AND Reactor Trip By-pass Breakers are OPEN.

(3) VERIFY APP-004-F5, MANUAL TRIP, is received.

(4) DEPRESS the FIRST OUT RESET pushbutton to acknowledge and clear APP-004-F5.

GP-003 Rev. 94 Page 24 of 60

Section 8.1 Page 11 of 11

8. .31 (Continued) JillI N E: he Reactor Trip Breakers are open, thus, the Stationary Gripper Coils are deenergized. This will change the magnetic coupling characteristics of the Individual Rod Position Indication Detectors. Some of the Rod Position Indications may have a slightly negative value (between zero and -5 inches) when checked on ERFIS.

Performance of the actions in Step 8.1.31.c is NOT used to establish compliance with ITS LCO 3.1.4 and 3.1.7. These checks are performed in Step 8.2.9.g.

These checks are used to verify the Rod Position Indication System is working correctly PRIOR to commencing the actions in Section 8.2. This ensures compliance with the meaning and intent of Precaution & Limitation (P&L) 5.4.2.

OMM-024, Rod Position Channel Check, may be used as a reference and guide for acceptance criteria while performing Step 8.1.31 .c.

c. CHECK that the Individual Rod Position Indication to Group Counter deviation criteria listed in OMM-024 is satisfied prior to withdrawing rods from the fully inserted condition.

GP-003 Rev. 94 Page 25 of 60

Section 8.2 Page 1 of 20 All steps shall either be initialed when performed or if the procedure intent is met by existing Plant conditions, the step shall be marked N/A and initialed by

/ the Shift Manager (SM).

If the safe, efficient operation of the Plant so dictates, the steps may be performed simultaneously or out of sequence.

Steps associated with Control Rod manipulation and the approach to Criticality should be performed in the order written.

jnstpictions for Taking the Reactor Critical this startup is immediately following a Refueling OR other core alteration, THEN this section involves PLP-037 Case I activities.

/

IF this startup is NOT immediately following a Refueling OR other core alteration, THEN this section involves PLP-037 Case II activities.

1. IF this startup has been determined to involve PLP-037 Case I OR Case II activities, THEN verify a pre-job briefing has been completed.

Miement Dgnated T4nitor signature GP-003 Rev. 94 Page 26 of 60

Section 8.2 Page 2 of 20 INIT CA ON Access inside Containment during the eactor Startup is restricted due to changing Radiological conditions. IF access is necessary during Startup, the activity should be coordinated with Radiation Protection.

2. IF access was made inside Containment (CV) during this shutdown, THEN perform the following:

a. INSPECT AND CLOSEOUT the CV lAW PLP-006.

b. WHEN the CV has been inspected and closed out lAW PLP-006 AND all discrepancies are resolved, THEN LOCK CLOSED the CV Personnel Hatch doors.

3. VERIFY with RC that access inside Containment during Reactor Startup is restricted due to changing Radiological conditions.

4. IF this is the initial startup following a core alteration, THEN PERFORM the following:

a. MARK the rest of Sections 8.2 AND 8.3 N/A.

b. PERFORM the Reactor startup lAW EST-050.

5. WHEN the RCS is at the Estimated Critical Boron Concentration, THEN REQUEST that the Reactor Engineer verify that the Moderator Temperature Coefficient (MTC) is less than or equal to

+5 pcm/°F (FMP-001).

Reactor Engineer Contact (Print name)

GP-003 I Rev. 94 I Page 27 of 69j

Section 8.2 Page 3of20 INIT BEGIN CRITICAL STEPS

6. OBTAIN permission to take the Reactor critical from the Manager

- Operations, OR the Plant General Manager, OR the individual who is designated Acting Plant General Manager.

Permission granted by:

Time/Date: 7t7L Printnan2

( TE: A dedicated Operator at the Controls and at least one other Licensed Operator shall be in the COs Watchstation during the Reactor Startup.

Until the completion of this GP, distractions in the Control Room should be minimized to allow full operator attention to the startup. (SOER 07-1, Recommendation #2)

Shift Turnover shall NOT be done unless the Reactor is stable AND Shutdown Bank rod withdrawal has NOT commenced, OR the Reactor is stable at I 0 amps. (SOER 07-1, Recommendation #2)

7. ANNOUNCE the following two times on the Plant Public Address System:

ATTENTION, REACTOR STARTUP HAS COMMENCED; ALL WELDING ACTIVITIES ARE SUSPENDED UNTIL FURTHER NOTICE.

GP-003 Rev. 94 Page 28 of 60

Section 8.2 Page 4 of 20 INIT

8. REVIEW AND APPLY the following items throughout the remainder of this procedure. /

ie Rod Group Alignment checks and the Rod Position Indication checks of ITS 3.1.4 and 3.1.7 are applicable in MODE 2 and MODE 1.

All RPIs should be verified as in alignment prior to entering MODE 2.

Øiticality shall be anticipated at any time when the Control Rods are being withdrawn, or when boron dilution operations are in progress.

he MAXIMUM Startup Rate allowable is 1.0 dpm.

rod motion is commenced, the Operator may stop rod motion as necessary to control the reactivity addition.

,checks of rod bottom lights, overlap, rod alignment, and stable counts shall be performed during the rod pulls, AND may be signed off when the Reactor is stable while plotting 1/M data.

a discrepancy is identified in rod position indication by rod bottom lights or rod position indication, rod speed, rod direction, or Nuclear Instrument response, the rod withdrawal shall be secured until the discrepancy is resolved.

HEN above 220 steps withdrawn, THEN Shutdown Banks should be withdrawn in 1 or 2 step increments to prevent overstepping of the control rods.

e Reactor shall be declared CRITICAL when the following conditions exist:

ROD MOTION AND TABLE POSITIVE STARTUP RATE AND TEADILY RISING COUNTS OR AMPS GP-003 Rev. 94 Page 29 of 60

Section 8.2 Page 5 of 20 INIT

9. WITHDRAW Shutdown Bank A by performing the following:

a. CHECK ALL Shutdown Bank and Control Bank Group Counters are reading 000.

b. IF any Group Counters are NOT reading 000, THEN PERFORM Step 8.1.31 prior to proceeding.

c. VERIFY the Reactor Trip Breakers CLOSED.

IdfE: ,) APP-005-E2, ROD CONT SYSTEM URGENT FAILURE, and APP-005-E3,

/ ROD CONT SYSTEM NON-URGENT FAILURE, may reflash when the ROD CONTROL STARTUP pushbutton is depressed. This is due to the various control, alarm and logic relays cycling and resetting.

d. DEPRESS the ROD CONTROL STARTUP pushbutton.

e. VERIFY APP-005-E2 AND APP-005-E3 are extinguished.

f. VERIFY the Group Step Counters indicate ZERO.

g. VERIFY Individual Rod Position Indicators are within 7.5 inches of the Bank average rod height.

N E: Performance of Step.8.2.9.h will ensure that the ERFIS Rod Misalignment Monitoring programs are properly enabled to perform the required automatic Rod Misalignment Checks of ITS LCO 3.1.4 and 3.1.7. Performance of these actions will not impact the various Pulse Counters in the Rod Control System.

h. Using the ERFIS Turn-on Code (TOC) RODUP, VERIFY ERFIS is showing all Control Rod Groups at 0 (zero) steps.

V SELECT SBA on the Rod Bank Selector switch.

GP-003 Rev. 94 Page30of60

Section 8.2 Page 6 of 20

.9 (Continued) LllI E: During Rod Withdrawal, the Operator at the Controls (OAC) is manipulating the Rod Withdrawal and monitoring applicable parameters. Simultaneously, a licensed RO other than the assigned OAC will assist in performing the Attachment 10.3, Control Rod Withdrawal Checklist.

TION When above 220 steps withdrawn, utdown Banks should be withdrawn in I or 2 step increments to prevent overstepping of the control rods.

j. WITHDRAW Shutdown Bank A to 225 steps AND PERFORM the checks of Attachment 10.3, Control Rod Withdrawal Checklist.

k. VERIFY the Source Range count rate stabilizes AND does NOT rise in an unexpected manner.

E: POWERTRAX is the official ECC/ECP calculation. The intent of the following step is to validate the POWERTRAX Estimated Critical Position (ECP) calculation using Attachment 10.1. The manual method (Attachment 10.1) can utilize any or all of the following: the plant curve book, POWERTRAX Pre-calculated Data, or updated data provided that data has been reviewed and approved. The intent of a second Estimated Critical Position (ECP) using a different method than the first is to ensure a common mistake is not made on both of the ECPs.

Reactor Engineering will provide multiple POWERTRAX ECC/ECP calculations. A manual ECP validation does not need to be performed for each and every POWERTRAX calculation. The manual ECP must be within the limits of Reference 2.3.46, FMP-025, POWERTRAX OSG, ECC and PDD Modules, when compared to the POWERTRAX calculation that is used as the official ECC/ECP. FMP-025 defines this limit as 250 pcm.

10. PERFORM at least two ECPs as follows: (Project 97-00161)

a. An ECP calculated by Reactor Engineer using POWERTRAX or a similar method.

b. An ECP calculated by Operations using Attachment 10.1, Estimated Critical Condition Form. (SOER 07-1, Recommendation 3)

GP-003 Rev. 94 Page 31 of 60

Section 8.2 Page 7 of 20 INIT

11. ATTACH all ECPs to this procedure for routing to the vault as permanent plant records. jL.

N  : RCS Boron concentration should be verified by two consecutive samples at 15 minute intervals AND are to be within 10 PPM of Estimated Critical Boron Concentration previously recorded. Pressurizer (PZR) boron concentration should be within 20 PPM of RCS Boron concentration.

(Reference 2.4.9, NCR 433838)

12. PERFORM a comparison of the Estimated Critical Boron Concentration and the actual RCS and Pressurizer (PZR) Boron concentrations as follows:

a. RECORD the Estimated Critical Boron Concentration provided by either Reactor Engineering OR the,/ -y calculated ECP. pp

b. RECORD RCS Boron concentration from two consecutive samples taken at 15 minute intervals.

• st 1

Sample: Time:77(&iJ at p

• rd 2

Sample: Time: AlLYt4) at pp /L-

c. RECORD Pressurizer (PZR) Boron concentration from two consecutive samples taken at 15 mi ute intervals. .

• st 1

Sample: Time: at 7ppmL d.

• id 2

Sample: Time: I1JO4&) at

Ø7 CHECK Pressurizer (PZR) Boron concentration within 20 ppm of RCS Boron concentration.

e. CHECK RCS Boron concentration within 10 ppm of Estimated Critical Boron Concentration.

GP-003 Rev. 94 Page 32 of 60

Section 8.2 Page 8 of 20 INIT

13. IF the current RCS Boron Concentration is NOT at the Estimated Critical Boron Concentration, THEN perform the following:

a. ADJUST RCS Boron Concentration per the Operation of RCS Makeup System for Automatic Makeup, Dilution, Boration and Alternate Dilute Section of OP-301.

b. WHEN the boron concentration adjustment is completed, THEN PERFORM the following:

(1) REQUEST an RCS AND PZR sample to determine the adjusted boron concentration AND COMPARE to the Estimated Critical Boron Concentration results previously recorded.

,f,1,4 RCS Boron ppm PZR Boron 4it4 ppm E&C Contact (Print name)

(2) WHEN 15 minutes have passed since the previous sample, THEN REQUEST a second RCS AND PZR sample to determine the adjusted boron concentration AND COMPARE to the Estimated Critical Boron Concentration results previously recorded.

RCS Boron A 1

/\J/ ppm

,AJ/,4 PZR Boron ppm E&C Contact (Print name)

AVAE GP-003 Rev. 94 Page 33 of 60

Section 8.2 Page 9 of 20 8.2.13 (Continued) J.tllI

c. WHEN the RCS AND PZR boron concentration sample results have been verified, THEN NOTIFY the Reactor Engineer of the results. (Project 97001 61)

RCS Boron ppm PZR Boron ppm Reactor Engineer Contact Print name)

d. IF the Reactor Engineer determines that the RCS boron concentration is NOT acceptable, THEN ADJUST RCS Boron Concentration per the Operation of RCS Makeup System for Automatic Makeup, Dilution, Boration and Alternate Dilute Section of OP-301 as necessary to achieve the required ECP boron concentration determined by Reactor Engineer.

Required RCS Boron /\4 ppm (1) WHEN the boron concentration adjustment is completed, THEN PERFORM the following:

(a) REQUEST an RCS AND PZR sample to determine the adjusted boron concentration AND COMPARE to the Estimated Critical Boron Concentration results previously recorded.

RCS Boron ppm PZR Boron j ppm E&C Contact Print name)

GP.-003 Rev. 94 Page 34 of 60

Section 8.2 Page 10 of 20 8.2.13.d(1) (Continued) INIT (b) WHEN 15 minutes have passed since the previous sample, THEN request a second RCS AND PZR sample to determine the adjusted boron concentration AND COMPARE to the Estimated Critical Boron Concentration results previously recorded.

RCS Boron ppm PZR Boron ppm

- E&C Contact ( rint name)

(2) WHEN the RCS AND PZR boron concentration sample results have been verified, THEN NOTIFY the Reactor Engineer of the results.

(Project 97-00161)

RCS Boron J i4 1 ppm PZR. Boron ppm

1) IA Reactor Engineer Contact (Print name)

14. VERIFY Reactor Engineer has determined the RCS boron concentration is acceptable.

_i+t JAI Reactor Engineer Contact (Print name)

15. RECORD the highest reading Source Range Channel, AND the highest reading Intermediate Range Channel.

Highest Source Range -

3 N- (ic Highest Intermediate Range N- f/O_ amps1

16. VERIFY the Audio Count Rate Channel Selector switch selected to the highest reading SR Channel. N- 3 J GP-003 Rev. 94 Page 35 of 60

Section 8.2 Page 11 of 20 I NIT

17. VERIFY the highest reading Intermediate Range Channel is . /

selected on the Corn paratort9rawer. N- \.3h The Reactor shall NOT be taken Critical below Minimum Control Rod Insertion Limit.

18. RECORD the Tech Spec Minimum Control Rod Insertion Limit for zero power from the COLR (FMP-001) OR from the Plant Curve Book, Curve 1.9AOR 1.9B, Rod Insertion Limit, on Attachment 10.2, Inverse Count Rate Ratio (1IM) Data and Plot Form.

19. REQUEST the MODE 2 Control Bank Position corresponding to 2000 PCM below the Target Critical position from Reactor Engineering AND record on Attachment 10.3, Control Rod Withdrawal Checklist (NCR 233326).

Reactor Engineer Contact (Print name) 6)ALL Nuclear Instruments shall be monitored and cross-checked against each other during the Startup. Both Source Range indications, both Intermediate Range indications, all Power Range indications, AND related current and rate indications should be included in the cross-checking. Audio Count Rate should also be used in the approach to Criticality. These indications should be used to verify Criticality indications as compared to ECP requirements. All anomalies should be immediately investigated. (SOER 88-02)

Complete Verbatim Procedure Compliance shall be observed AND conservative actions always taken for all Control Rod movement during Startup. (SOER 88-02)

20. RECORD ECP data required in Attachment 10.3, Control Rod Withdrawal Checklist.

GP-003 Rev. 94 Page 36 of 60

Section 8.2 Page 12 of 20 INIT

21. PERFORM the following:

a. BLOCK the HI FLUXAT SHUTDOWN ALARM on N-31 AND N-32.

b. VERIFY APP-005-B1, HI FLUX AT SHUTDOWN ALARM BLOCK, is ILLUMINATED.

c. CHECK that the POWER ABOVE P-6 permissive light is EXTINGUISHED. (ITS SR 3.3.1.8)

d. CHECK that the POWER ABOVE P1 0 permissive light is EXTINGUISHED. (ITS SR 3.3.1.8)

R 3.1 .6.1 requires verification that the estimated critical control bank position is within the limits specified in the COLR within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> prior to achieving criticality. To support this SR, criticality must be achieved within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of a POWERTRAX critical condition prediction AND the minimum rod position predicted for criticality shall be greater than the minimum control bank position for criticality specified in the COLR. The following step ensures that sufficient time remains to achieve criticality on the current ECP.

The Rod Alignment Checks of ITS 3.1.4 and 3.1.7 are applicable once the Reactor has entered MODE 2.

The actions of Step 8.2.22.2 are continuous actions AND are applicable through all subsequent steps of the Reactor startup.

The Rod Insertion Limits are found in FMP-001, Core Operating Limits Report (COLR), and Plant Curves 1.9Aand 1.9B.

22. WITHDRAW Shutdown Bank B as follows:

a. Using either Plant Curve I .9A or I .9B, PERFORM the following:

(1) RECORD the current core EFPD.

(2) DETERMINE the Rod Insertion Limits for the current core EFPD and zero percent power. I GP-003 Rev. 94 Page 37 of 60

Section 8.2 Page 13 of 20 8.2.22.a (Continued) INIT (3) RECORD which Plant Curve was CURVE I .9A (Circle curve use (4) RECORD the Rod Insertion Limits for the following:

Control Bank C Steps Control Bank D Steps

b. PERFORM the following check every 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> until critical to satisfy requirements of ITS SR 3.1.6.1: A Estimated time Minimum Rod Position (500 PCM Within COLR limits?

of ECC/ECP below the ECC) Bank / Steps (Circle one)

)NO YES/NO YES I NO YES / NO I YES/NO

c. IF the control bank positions shown on the POWERTRAX printout for the estimated time of the ECC/ECP are NOT within the control bank insertion limits specified in the COLR, THEN PERFORM the following:

(1) INSERT all control banks to 0 steps. ,J44 (2) MARK the remaining steps in Section 8.2 as N/A AND PERFORM the required actions of Section 8.3 for a missed or aborted startup.

d. SELECT SBB on the Rod Bank Selector switch.

GP-003 Rev. 94 Page 38 of 60

Section 8.2 Page 14 of 20 8.2.22 (Continued)  !.NiI NOTE: During Rod Withdrawal, the Operator at the Controls (OAC) is manipulating the Rod Withdrawal and monitoring applicable parameters. Simultaneously, a licensed RO other than the assigned OAC will assist in performing the Attachment 10.3, Control Rod Withdrawal Checklist.

CAUTION When above 220 steps withdrawn, Shutdown Banks should be withdrawn in 1 or 2 step increments to prevent overstepping of the control rods.

e. WITHDRAW Shutdown Bank B to 225 steps while performing the checks of Attachment 10.3, Control Rod Withdrawal Checklist.

f. IF an alternate MODE 2 Declaration Point has NOT been established AND Shutdown Bank B is greater than 20 steps, THEN PERFORM the following (NCR 233326):

MAKE a plant announcement that MODE 2 has been entered.

CHANGE the ERFIS Mode indication to display MODE 2 by using the PMODE function.

g. IF an alternate MODE 2 declaration point has been established, THEN PERFORM the following:

(NCR 233326)

(1) WHEN the Control Banks reach the position calculated for MODE 2 recorded in Attachment 10.3, Control Rod Withdrawal Checklist, THEN PERFORM the following:

MAKE a plant announcement that MODE 2 has been entered.

CHANGE the ERFIS Mode indication to display MODE 2 by using the PMODE function.

GP-003 Rev. 94 Page 39 of 60

Section 8.2 Page 15 of 20 8.2.22 (Continued) INJI

h. VERIFY the Source Range count rate stabilizes AND does NOT rise in an unexpected manner.

NOTE: A minimum of four inverse count rate ratio (1/M) data points are required on the approach to criticality. The data points should be taken each time the count rate approaches a value that is approximately twice the previous stable data point. This is referred to as doubling. The first data point, Reference Count

), is obtained after Shutdown Bank A and Shutdown Bank B have Rate (CR 0

been fully withdrawn.

The Audio Count Rate VOLUME AND AUDIO MULTIPLIER should be adjusted as the count rate rises to maintain a distinguishable audible count rate.

23. WHEN Shutdown Bank A and Shutdown Bank B are fully withdrawn AND the count rate is stable, THEN RECORD the time AND Reference Count Rate (CR ) on Attachment 10.2, Inverse 0

Count Rate Ratio (1/M) Data and Plot Form.

GP-003 Rev. 94 Page 40 of 60

Section 8.2 Page 16 of 20 INIT NOTE: The following FOUR steps are continuous actions steps which remain in effect until the actions have been performed or plant conditions render the steps not applicable.

CAUTION A minimum of one decade overlap between Source Range and Intermediate Range Channels is required prior to blocking the Source Range Reactor Trip signals.

24. WHEN Reactor power is indicating in the Intermediate Range, THEN PERFORM the following:

a. SELECT the highest reading Intermediate Range Channel on the Comparator and Rate Drawer. N

b. VERIFY one decade overlap between the Source Range and Intermediate Range indication.

NOTE: One Intermediate Range greater than 10.10 amps is required to satisfy the P-6 Permissive.

25. WHEN one Intermediate Range detector indicates greater than 10° amps, THEN VERIFY the POWER ABOVE P-6 permissive light ILLUMINATES. (ITS SR 3.3.1.8)

26. WHEN both Intermediate Range channels indicate greater than 10b0 amps, THEN BLOCK the Source Range Reactor Trip by depressing the SOURCE RANGE LOGIC TRIP DEFEAT TRAIN A AND the SOURCE RANGE LOGIC TRIP DEFEAT TRAIN B pushbuttons on the RTGB

27. VERIFY the following:

a. All Source Range indication goes to zero.

b. The SR DET LOSS OF DC Annunciator (APP-005-A1)

ILLUMINATED.

GP-003 Rev. 94 Page 41 of 60

Section 8.2 Page 17 of 20 INIT NOTE: The approach to criticality should take approximately four doublings of the indicated Reference Count Rate (CR ) under ideal conditions. The target count 0

rate is intended to serve as a known stable reactivity state suitable for data taking and criticality predictions.

It is NOT necessary to attempt to stabilize at exactly double the previous count rate, therefore the use of a target count rate (as applied to each doubling of the count rate) is intended to allow the Operator to stabilize the core as close as is practical to the doubling count rate without excessive rod motion.

APP-005-F2, ROD BOTTOM ROD DROP, will extinguish when Control Bank A is above 20 steps.

28. WITHDRAW control rods to achieve the target count rate determined in Attachment 10.2, Inverse Count Rate Ratio (IIM)

Data and Plot Form, as follows:

a. SELECT M on the Rod Bank Selector switch.

NOTE: During Rod Withdrawal, the Operator at the Controls (OAC) is manipulating the Rod Withdrawal and monitoring applicable parameters. Simultaneously, a licensed RO other than the assigned OAC will assist in performing the Attachment 10.3, Control Rod Withdrawal Checklist.

b. WITHDRAW Control Rods until count rate is approximately equal to the target count rate while performing the checks and verifications of Attachment 10.3, Control Rod Withdrawal Checklist.

c. VERIFY the count rate stabilizes AND does NOT rise in an unexpected manner.

d. IF criticality is indicated, THEN GO TO Section 8.3.

GP-003 Rev. 94 Page 42 of 60

Section 8.2 Page 18 of 20 INIT NOTE: Each successive reactivity addition will require less rod motion and a longer time for the count rate to stabilize. The NR-45 trace should be closely monitored and cross-checked against available instrumentation to determine when count rate has stabilized following each successive rod pull to double counts.

29. WHEN rod motion has been stopped AND count rate is stable, THEN RECORD the required information on Attachment 10.2, Inverse Count Rate Ratio (1/M) Data and Plot Form.

30. WITHDRAW control rods to achieve the new target count rate determined in Attachment 10.2, Inverse Count Rate Ratio (1/M)

Data and Plot Form, as follows:

NOTE: During Rod Withdrawal, the Operator at the Controls (OAC) is manipulating the Rod Withdrawal and monitoring applicable parameters. Simultaneously, a licensed RO other than the assigned OAC will assist in performing the Attachment 10.3, Control Rod Withdrawal Checklist.

a. WITHDRAW Control Rods until count rate is approximately equal to the target count rate while performing the checks and verifications of Attachment 10.3, Control Rod Withdrawal Checklist.

b. VERIFY the count rate stabilizes AND does NOT rise in an unexpected manner.

c. IF criticality is indicated, THEN GO TO Section 8.3.

31. WHEN rod motion has been stopped AND count rate is stable, THEN RECORD the required information on Attachment 10.2, Inverse Count Rate Ratio (1/M) Data and Plot Form.

GP-003 Rev. 94 Page 43 of 60

Section 8.2 Page 19 of 20 INIT

32. WITHDRAW control rods to achieve the new target count rate determined in Attachment 10.2, Inverse Count Rate Ratio (1/M)

Data and Plot Form, as follows:

NOTES: During Rod Withdrawal, the OperatorAt The Controls (OAC) is manipulating the Rod Withdrawal and monitoring applicable parameters.

Simultaneously, a licensed RO other than the assigned OAC will assist in performing the Attachment 10.3, Control Rod Withdrawal Checklist.

a. WITHDRAW Control Rods until count rate is approximately equal to the target count rate while performing the checks and verifications of Attachment 10.3, Control Rod Withdrawal Checklist.

b. VERIFY the count rate stabilizes AND does NOT rise in an unexpected manner.

c. IF criticality is indicated, THEN GO TO Section 8.3.

33. WHEN rod motion has been stopped AND count rate is stable, THEN RECORD the required information on Attachment 10.2, Inverse Count Rate Ratio (1/M) Data and Plot Form.

34. After the third doubling, IF the predicted critical rod position from the 1/M plot falls outside the +1-500 pcm position,(minimum and maximum rod position) THEN NOTIFY the SM AND Reactor Engineer for further guidance (Project 97-00161).

35. IF the predicted Critical Rod Position is within the Minimum and Maximum Rod Position recorded on Attachment 10.3, Control Rod Withdrawal Checklist, THEN NIA Steps 8.2.36 through 8.2.37 at the discretion of the SM AND GO TO Step 8.2.38.

GP-003 Rev. 94 Page 44 of 60

Section 8.2 Page 20 of 20 INIT

36. WITHDRAW control rods to achieve the new target count rate determined in Attachment 10.2, Inverse Count Rate Ratio (1/M)

Data and Plot Form, as follows:

NOTE: During Rod Withdrawal, the Operator At The Controls (OAC) is manipulating the Rod Withdrawal and monitoring applicable parameters. Simultaneously, a licensed RO other than the assigned OAC will assist in performing the Attachment 10.3, Control Rod Withdrawal Checklist.

a. WITHDRAW Control Rods until count rate is approximately equal to the target count rate while performing the checks and verifications of Attachment 10.3, Control Rod Withdrawal Checklist.

b. VERIFY the count rate stabilizes AND does NOT rise in an unexpected manner.

c. IF criticality is indicated, THEN GO TO Section 8.3.

37. WHEN rod motion has been stopped AND count rate is stable, THEN RECORD the required information on Attachment 10.2, Inverse Count Rate Ratio (1/M) Data and Plot Form.

38. PERFORM the following:

a. WITHDRAW Control Rods as necessary to achieve criticality OR to the Maximum Rod Position recorded on Attachment 10.3, Control Rod Withdrawal Checklist.

b. WHEN the following occur, THEN DECLARE the Reactor critical AND RECORD the time.

The count rate is STEADILY RISING.

The STARTUP RATE is STABLE and POSITIVE.

There is NO ROD MOTION in progress. Time CAUTION Radiological conditions inside Containment change during Reactor power alterations.

Personnel requiring Containment entry after criticality shall coordinate with RC prior to entry.

39. VERIFY with SM/CRS restricted access inside Containment due to Reactor Startup is no longer required AND INFORM RC the unit is critical.

GP-003 I Rev. 94 I Page 45 of 60

ATTACHMENT 10.1 Page 1 of 6 ESTIMATED CRITICAL CON DITION)FORM Criticality# Control Operator C Date SM___________

1 .0 PREVIOU CRITICAL CONDITION for (hrs.) on 2- 4 0

Uc 4 4 1Date)

CLI E: Critical data from initial Startup Physics Testing should be used when calculating the ECP if this startup is to be performed during the first 5 EFPD of the fuel cycle.

Siemens methodology accounts for the reactivity contribution associated with the difference in temperature on the integral boron worth by including the reactivity contribution into the Power Defect Curve and POWERTRAX.

Therefore, integral boron worth is calculated based upon no load temperature of 547°F and Hot Zero Power (HZP) condition.

The POWERTRAX ECC/ECP is the official estimate. (Reference to Precaution

& Limitation 5.4.l4and FMP-025)

Previous Critical Data should be from Equilibrium Conditions (i.e., Steady State Power for a minimum of 72 hrs). The use of Critical Data from non-equilibrium conditions must be adjusted or it can provide inaccurate ECP results.

INIT 1.1. IF ECP is following a mid-cycle shutdown (greater than 30 days),

THEN CONSIDER Plutonium build in effects AND OBTAIN Reactor Engineering input fpr the ECP.

Reactor Engineering Contact (Print name) 1.2. Rod Position on Controlling Bank (Critical Data Stamp)

I) was 1.3. Power Level (Critical Data Stamp)

GP-003 Rev. 94 Page 51 of 60

ATTACHMENT 10.1 Page 2 of 6 ESTIMATED CRITICAL CONDITION FORM 1.4. Boron Concentration: lli!I 1.4.1. RECORD Boron Concentration (Critical Data Stamp) 1.4.2. RECORD number of days between date of last Critical Data Stamp and start of shutdown: & days If the time between last Critical Data Stamp and shutdown is less than or equal to one day, then calculating an adjusted current boron concentration is NOT necessary.

1.4.3. IF shutdown less than or equal to one day after last Critical Data Stamp, THEN GO TO Step 1.4.6 AND RECORD Critical Data Stamp Boron Concentration as the Current Critical Boron Concentration.

1.4.4. RECORD the observed change in RCS boron concentration per day for the last week prior to the last Critical Data Stamp (positive if rising, negative if lowering). ( ) IAJ7,4 ppm/day____

1.4.5. CALCULATE Boron Concentration Change since last Critical Data Stamp (Multiply days in Step 1.4.2 by change ppm/day in Step 1.4.4).

) iJ44 ppm 1.4.6. RECORD CALCULATED Critical Boron Concentratio (Step 1.4.1 pIus Step 1.4.5, if applicable) 1.5. Integral Boron Worth (Curve 1.13 or POWERTRAX using CALCULATED Critical Boron Concentration)

(Use curves or data based upon 547°F, HZP) g pcm GP-003 Rev. 94 Page 52 of 60

ATTACHMENT 10.1 Page 3 of 6 ESTIMATED CRITICAL CONDITION FORM INIT 1.6. Xenon Worth (Curve 2.1 or POWERTRAX) 7 1.7. Power Defect Worth (Curve 1.3 or POWERTRAX) 4 fpcm ib7-1.8. Samarium Worth (Curve 2.4A, 2.4B, 2.5 or POWERTRA 2 X) 7o pcm 1.9. Inserted Rod Worth at Power (Curve 1.6, 1.8 or 3 POWERTRAX) / pcm f/L IF previous critical data is NOT from equilibrium conditions, THEN contact the Reactor Engineer for Xenon Worth.

2 At the Beginning of Life (BOL) prior to reaching the equilibrium Samarium Value use Curve 2.5 or POWERTRAX data. After equilibrium Samarium concentration is reached, use Curve 2.4A (BOL) or Curve 2.4B (EOL), interpolating as necessary, or use POWERTRAX data.

IF previous rod position was greater than 128 steps on Bank D, THEN use the Full Power Rod Worth Curve 1.6. For rod positions less than 128 steps on Bank D, Curve 1.8 should be used.

2.0 PROJECTED CRITICAL CONDITIONS for A M

4 )on (h rs.) (Date),

2.1 Boron Concentration (Actual) i/ç7 ppm 2.2 Average Temperature (Actual)

(Achieve Criticality 547°F) 2.3 Hours Since Shutdown 2.4 Integral Boron Worth (Curve 1.13 or POWERTRAX) 4Zpcm (Use curves or data based upon 547°F, HZP) 2.5 Xenon Worth (Curve 2.3 or POWERTRAX) 7/9 cm E: Depending on the time in core life (burn-up) and the time since shutdown, it may be necessary to interpolate between both Curve 2.4A and 2.4B.

2.6 IF Samarium Worth is at equilibrium, THEN DETERMINE Samarium worth using one of the following Curve 2.4A (BOL) interpolating as necessary. pcm Curve 2.4B (EOL) interpolating as necessary./2_Z*cm POWERTRAX data. pcm GP-003 Rev. 94 Page 53 of 60

ATTACHMENT 10.1 Page 4 of 6 ESTIMATED CRITICAL CONDITION FORM INIT 2.7 IF the startup is due to a trip before equilibrium Samarium is reached, THEN ADD the change as determined from Curve 2.4A to the previous Samarium worth of Step 1.8.

Step 1.8 Al/A pcm + Change (Curve 2.4A)A)M pcm = 4pcm 3.0 REACTIVITY CHANGES FROM PREVIOUS CRITICAL TO PROJECTED CRITICAL Complete the following table as follows:

3.1 ENTER the required information.

(Each value entered into the PREVIOUS and PROJECTED fields should be entered as POSITIVE NUMBERS.

3.2 PERFORM the designated calculations to determine the change in each parameter and the total change in reactivity.

Previous Action Projected Result

1. Integral Boron Worth Subtract

/2z,2 t =3B cm

(

2. Xenon Worth 2$ 7 Subtract 7,9 2 Z/o 7 pcm

=

3. Samarium Worth Subtract = pcm

4. Power Defect 9 r2 Subtract 0 7Pcm

= 2?

5. Change in Reactivity

/ 9 pcm 4.0 REACTIVITY BALANCE 4.1 New Controlling Rod Worth = ( 2_ 1Z22L c?

Inserted Rod Worth + Chahge in Reativity (Step 1.9) (Step3.2.5) j

= /2/2,, PCM2L 4.2 RECORD the New Controlling Rod Worth clcuIate.on the ECP provided by the Reactor Engineer. (2-1> PCM 4.3 IF the results of the two ECPs are not within 250 pcm of each other, THEN CONTACT the Reactor Engineer for further actions. I J )A 4.4 New critical rod position associated with the integral worth in Step 4.1 as determined from Curve 1.8 / (3?

2 c Steps on Bank GP-003 I Rev. 94 Page 54 of 60

ATTACHMENT 10.1 Page 5 of 6 ESTIMATED CRITICAL CONDITION FORM INIT 5.0 ESTIMATED CRITICAL CONDITION 5.1 Shutdown A 225 Steps*

Shutdown B 225 Steps*

Control A 225 Steps*

Control B 225 Steps*

Control C / 5 Steps Control D Sjeps Boron .6 / ppm T-AVG 7 1

L °F These banks shall b at 225 steps except for physics tests.

5.2 Is the position above the minimum in ertio limits?

(ITS SR 3.1.6.1) c::: 44A1L 6D (Tle one)

NOZ1Ml 5.3 Is the position less than or equal to YES NOJZ, 225 steps on Bank D? ci c e one) 6.0 CALCULATE the tolerance band of plus OR minus 500 pcm from the ECP.

6.1.1 Maximum rod position j .,

(Manual ECP 500 pcm): I K Steps on Bank 6.1.2 Minimum rod position , J, /

(Manual ECP + 500 pcm): Steps on Bank The Minimum and Maximum rod positions to reflect +500 and -500 pcm, respectively are indicated on the POWERTRAX Estimated Critical Condition Module results data sheet as Low and High Rod Position. The values are referenced against CBD at zero steps. Negative values represent CBD at zero and CBC at 128 steps minus the negative value indicated (i.e. POWERTRAX rod position is -10 steps relates to CBD at zero steps and CBC at 118 steps).

6.1.3 RECORD the maximum and minimum rod positions from the POWERTRAX ECC/ECP.

Maximum rod position on Bank Minimum rod position Steps on Bank GP-003 Rev. 94 Page 55 of 60

ATTACHMENT 10.1 Page 6 of 6 ESTIMATED CRITICAL CONDITION FORM 7.0 ESTABLISH the time window for acceptable ECP results. INIT 7.1 REVIEW the POWERTRAX ECP Estimated Critical Condition Module results data sheet to establish a time window of acceptable ECP results, ensuring that the estimated time for achieving criticality reflects the Minimum Rod Position is above Rod Insertion Limit. 7 7.2 INDICATE the start and end step#, date, and time to establish a window below:

E: To allow the use of these ECPs, criticality must be achieved within the time window recorded below. This will ensure compliance with ITS SR 3.1.6.1.

The START STEP and END STEP are from the POWERTRAX ECC/ECP printouts.

Start Step#97 44J Date4j,4 , Time A41A)

End Step# ..t1 Time_______

7.3 ATTACH the POWERTRAX ECP Estimated Critical Condition Module results data sheet to this procedure.

Performed byYE9 i2r7%_

Approved by:

CRS or SM Signature GP-003 Rev. 94 Page 56 of 60

ATTACHMENT 10.2 Page 1 of 3 INVERSE COUNT RATE RATIO (1/M) DATA AND PLOT FORM

1. LOG 1IM data as it is acquired following rod withdrawal in Table 1 of this attachment.

2. PLOT the reference count rate (CR

) versus Control Rod Bank and Step position 0

on the 1/M Plot Form.

3. WHEN CR 1 data is available, THEN DIVIDE CR 0 by CR 1 = 1

/

0 (CR CR 1/M).

4. PLOT the results versus Control Rod Bank and Step position on Attachment 10.2, Inverse Count Rate Ratio (1IM) Data and Plot Form, for Source Ranges AND Intermediate Ranges.

NOTE: Extrapolations should extend through the X-AXIS at rod positions greater than the ECP and approach the ECP as the second and third points are plotted and extrapolated.

CONNECT the new point with the previous point AND extend the line (extrapolate) through the X-AXIS (predicted Critical Rod Position).

LOG the predicted Critical Rod Position on Table 1 as the LOWEST PROJECTED CRITICAL POSITION.

5. VERIFY that the Lowest Critical Rod Position is above the Minimum Insertion Limit.

6. CALCULATE the target count rate for the next doubling by multiplying the current count rate by two and log the result on Table 1 of this attachment.

7. REPEAT Steps 3 through 6 of this attachment for each ECP extrapolation using CR through CR 2 4 acquired in Section 8.2 in place of CR1 as shown on Table I of this attachment.

GP-003 Rev. 94 Page 57 of 60

c ATTACHMENT 10.2 Page 2 of 3 INVERSE COUNT RATE RATIO (IIM) DATA AND PLOT FORM NOTE: After the third doubling, if the predicted critical rod position from the IIM plot falls outside the +1-500 pcm position, the Reactor Operator should notify the SM and Reacto r Engineer for further guidance.

(Project 97-00161)

Minimum Insertion Limits: Steps on Bank C I Steps on Bank D TABLE I I LOWEST STEP LOWEST PROJECTED TIME ROD NI- NI-_

1/M 1/M PROJECTED CR11 POS. TARGET os. coOiW AMPS CRITICAL ABOVE MIN COUNT RATE POSITION INSERTION LIMIT (INIT) 8.2.23 =

0 CR 0 CR

/cR 1.0 =

0 CR 0 CR

=

/CR 1.0 2*cRo=

8.2.29 =

1 CR 1 0

CR

CR

1 CR 1

/

0 CR

CR

1 2*CR 8.2.31 =

2 CR 2

/

0 CR

CR

2 CR 2

/

0 CR

CR

2 2*CR 8.2.33 =

3 CR 3

/

0 CR

CR

3 CR 3

/

0 CR

= CR 3 2*CR 8.2.37 CR= 4

/

0 CR

CR

4 CR 4

/

0 CR

= CR C.

DATE: STARTUP#: 1/MPLOTTER:

GP-003 Rev. 94 Page 58 of 60

Q) C ATTACHMENT 10.2 Page 3 of 3 INVERSE COUNT RATE RATIO (IIM) DATA PLOT FORM 1.00 0.90 o.as_

0.80 O70_

n o

055 1 11HfIf II-II IffHRl*H1I 0.40 0.35 0.30 0.2 0.2Q_

0.15 0.10

(,n o

[IilIIIIIIlII 20 40 60 80 100 12Q1 I

CONTROL BAN ii 0 20 40 60 80 ibo 120 140160180200220 0 20 40 60 80 100120140160180200220 CONTROL BANK B CONTROL BANK D GP-003 Rev. 94 Page 59 of 60

ATTACHMENT 10.3 Page 1 of I CONTROL ROD WITHDRAWAL CHECKLIST

1. Record the MODE 2 Control Bank Position corresponding to 2000 PCM below the Target Critical position (NCR 233326).

5? Steps on Bank (.

2. Record the following ECP data from Attachment 10.1, Estimated Critical Condition Form, OR from the POWERTRAX computer generated ECP (N/A blanks not used):

Minimum Rod Position Maximum Rod Position:

Estimated lime of Criticality (500 PCM below the ECC): Expected Critical Rod Position:

Bank and steps (500 PCM above the ECC)

Bank and steps Bank and steps REQUIREMENT Rod Speed = 66-70 steps/mm Rod Speed = 43-47 steps/mm Rod Bottom Lights extinguished between 9 and 33 steps (200 steps, each rod within 7.5 inches of BankAvgbyRPl (2) (1)

,< 1/C 200 steps, each rod within 15 inches of Bank by Step Counter (2)

Bank Overlap: WHEN CB A at 129 steps, THEN CB B started Bank Overlap: WHEN CB B at 129 steps, THEN CB C started Bank Overlap: WHEN CB C at 129 steps, THEN CB D started.

(1) May be marked NIA if n ecked. (2) Reference ITS LCD 3.1.4 and 3.1.7, applicable in MODEs 1 & 2.

Performed by:

44 Initials Name (Print)

Approved by:

CRS or SM Signature GP-003 Rev. 94 Page 60 of 60

CONTINUOUS USE H. B. ROBINSON STEAM ELECTRIC PLANT. UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 3 PART 5 ABNORMAL OPERATING PROCEDURE AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM REVISION 26 Page 1 of 76

AOP-O0i. Revision 26 Summary Of Changes (PRR 429230)

ENTRY CONDITIONS Replaced the word unwarranted with unexpected to the types of rod motion. (PRR 418409)

Main Procedure Various Added titles of the sections to facilitate Steps finding the correct entry point in these procedures. (Editorial)

Various Changed Path-i to Path-i or EOP-E-0 in preperation Steps for EOP upgrade. (PRR 464456)

Section A Step ii.c Added AFD - Within Operating Band check and RNO with the appropriate RNO actions.

(PRR 429230)

Step i2.c Changed increase to raise for human error prevention. (Editorial)

Step 3i.b.2 Changed to allow the P to A converter to be raised or lowered, previously it was only allowed to be lowered. (PRR 429230)

N36 This note was added to inform Operators that AOP-007 is not required to be entered as the Operator is taking control of the Turbine.

(PRR 429230)

Step 40 Added ITS 3.1.1 to the Technical Specifications that should be reviewed by the Operators.

(PRR 429230)

AOP-OOi Rev. 26 Page 2 of 76

AOP-O01, Revision 26 Summary Of Changes (PRR 429230)

Section B Step 13.a Changed step so that now when the Operator

& 21 a is checking SDM being adequate. they are directed to FMP-012 for direction. (PRR 436602)

Step 13b. As the procedure GP-0O6 has been changed, made 2Lb & changes to this procedure to reflect that the 22 RNO information is now located in GP-006-1 or 2.

(PRR 462956)

N59 Added this note to inform the Operators that AOP-007 should NOT be used in response to the following steps.

(PRR 429230)

Section D Step 1 RNO Added another item to check to determine why power is not available to IRPI. (PRR 430089)

Attachment 1 Step 6 Added the option to press the HOLD button as well as the Go button. (PRR 398019)

AOP-O01 Rev. 26 Page 3 of 76

Rev. 26 AOP-OOl MALFUNCTION OF REACTOR CONTROL SYSTEM Page 4 of 76 j__STEP_H INSTRUCTIONS J I RESPONSE NOT OBTAINED I

1. PURPOSE This procedure provides the instructions necessary for the Operator to recover a dropped rod, realign a misaligned rod, stop abnormal continuous rod motion and operate with an IRPI failure.

This procedure is applicable in Modes 1, 2, and 3 with the exception of IRPI which is MODE 2 and MODE 1.

2. ENTRY CONDITIONS Any indication of a dropped rod, misaligned rod, unexpected rod motion, inability to move rod(s) or suspected IRPI malfunction.

It is not intended to enter AOP-OOl while in MODE 3 during a startup when the MODE 1 and MODE 2 ITS 3.L7 alignment limits of 7.5 inches of the average of the individual IRPIs in the associated bank when < 200 steps or IRPI within 15 inches of the associated bank demand position when > 200 steps are exceeded due to normal indicator drift during a startup while in MODE 3.

- END -

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 5 of 76

-iH INSTRUCTIONS RESPONSE NOT OBTAINED NOTE Steps 1 through 3 are Immediate Action Steps.

1. Check Unexpected Rod Motion - IN Go To Step 7.

PROGRESS

2. Check Reactor Power - GREATER Trip the Reactor Go To THAN 15% Pathi or EOP-E-O, Reactor Trip or Safety Injection.

3. Check Turbine Load -

Attempt To Stop Rod Motion As Follows:

• CONTROL RODS STEPPING IN

a. IF ROD BANK SELECTOR Switch AND position in A (AUTO), THEN Place the ROD BANK SELECTOR

• UNEXPECTED LOAD REDUCTION IN Switch in M (Manual)

PROGRESS

b. IF ROD BANK SELECTOR Switch OR in N (Manual) OR Individual Bank Select, THEN Place the

• UNEXPECTED LOAD REDUCTION ROD BANK SELECTOR Switch in A HAS OCCURRED (Auto).

IF Rod Motion does stop, THEN Trip the Reactor and Go To Path-i or EOP-E-O. Reactor Trip or Safety Injection.

Go To Step 5.

4. Go To AOP-015, Secondary Load Rej ection

5. Make PA Announcement For Procedure Entry

6. Go To Section C. Continuous Rod Motion

7. Make PA Announcement For Procedure Entry

Rev. 26 AOP-OOi MALFUNCTION OF REACTOR CONTROL SYSTEM Page 6 of 76 f STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED I

8. Determine If Multiple Rods Have Dropped As Follows:

a. Analyze Indications For Multiple Rod Drop

• Prompt Drop - PRESENT

• More than 1 Rod Bottom Light - ILLUMINATED

• More Than 1 IRPI -

INDICATES ON BOTTOM

b. Check Multiple Dropped Rods - b. Go To Step 11.

PRESENT

9. Check Reactor Status - MODE 1 OR Go To Section A, Dropped Rod 2

10. Trip The Reactor and Go To Path-i or EOP-E-O, Reactor Trip Or Safety Injection.

11. Check Tavg - TRENDING TO Tref Perform Attachment 1, Turbine Load Adjustment, to restore Tavg within -1.5 to +1.5°F of Tref.

Rev. 26 AOP-OOl MALFUNCTION OF REACTOR CONTROL SYSTEM Page 7 of 76 j STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED I

12. Determine The Status Of Rods As Follows:

a. Analyze the below indications for a dropped rod:

• APP-005-A3, PR DROP ROD -

ILLUMINATED

• APP-005-F2. ROD BOTTOM ROD DROP - ILLUMINATED

• Rod Bottom Light for affected rod - ILLUMINATED

• Indication of Prompt Drop

- PRESENT

• Quadrant Power Tilt indications - PRESENT

• APP-O05-F3, PR UPPER CH HI FLUX DEV/AtJTO DEFEAT - ILLUMINATED

• APP-005-F4. PR LOWER CH HI FLUX DEV/AIJTO DEFEAT - ILLUMINATED

• APP-005-C3, PR CHANNEL DEV -

ILLUMINATED

• Power Range Drawer Indications

b. Check Dropped Rod - PRESENT b. Observe the NOTE prior to Step 14 and Go To Step 14.

13. Go To Section A. Dropped Rod

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 8 of 76 STEP H INSTRUCTIONS 1 I RESPONSE NOT OBTAINED I

NOTE

• L there is any doubt as to IRPI failure 2R actual rod misalignment, THEN asspme rod misalignment is present.

• Malfunctioning IRPI(s) may be identified by erratic or drifting IRPI indication when the associated Rod Bank is not being moved, or sudden large changes in IRPI indication -with no corresponding change in nuclear power or motion of other rods in the associated bank.

• ERFIS Rod Position Indication may be used for IRPI indication below.

14. Determine The Status Of IRPI As Follows:

a. Analy2e the below indications for an IRPI problem:

IRPI Indication

• Indicator drift with NO flux effects

• Erratic indicator movement with NO flux

- effects

• Indicator off-scale High QE Low with NO flux effects Dropped Rod Indication with no flux changes

• Rod Bottom Light for affected rod -

ILLUMINATED AND

• APP-005-A3, PR DROP ROD - EXTINGUISHED (CONTINUED NEXT PACE)

Rev. 26 AOP-OOl MALFUNCTION OF REACTOR CONTROL SYSTEM Page 9 of 76 J STEP H INSTRUCTIONS RESPONSE NOT OBTAINED

14. (CONTINUED)

Simultaneous loss of ALL IRPI Indication (Power Supply Failure) - PRESENT

b. Check IRPI malfunction - b. Go To Step 16.

PRESENT

15. Go To Section D. Individual Rod Position Indication Malfunction

16. Determine The Status Of Rods As Follows:

a. Analyze below indications of An Immovable Misaligned Rod

• Rod - CAN NOT BE MOVED

• APP-0O5-E2, ROD CONT SYSTEM URGENT FAILURE -

ILLUMINATED

• Rod Indication - OUT OF ALIGNMENT WITH REMAINDER OF BANK

b. Check Misaligned/Immovable b. Reanalyze procedure entry Rod - PRESENT conditions.

IF conditions do NOT warrant AOP-OOl use, THEN return to procedure and step in effect.

IF a Rod Control malfunction exists. THEN Go To Step 1.

17. Go To Section B, Immovable/Misaligned Rods

- END -

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 10 of 76 STEP H INSTRUCTIONS I I SECTION A RESPONSE NOT OBTAINED I

DROPPED ROD (Page 1 of 23)

1. Check Plant Status - MODE 1 Observe CAUTION prior to Step 35 and Go To Step 35.

2. Check Dropped Rod Location - IN Observe the CAUTION prior to CONTROLLING BANK Step 4 and Go To Step 4.

NOTE Key #13 is required to open the Lift Coil Disconnect Panel Door.

3. Place Lift Coil Disconnect Switch For The Dropped Rod, In The OFF Position CAUTION Equipment repairs or manipulations to correct the cause of the dropped rod prior to procedural direction could inadvertently withdraw the dropped rod.

4. Notify Reactor Engineering A11J2 I&C Personnel To Perform The Following:

a. Verify the statuS of the dropped rod

b. Investigate the cause of the dropped rod

c. Avoid ANY action that could cause inadvertent withdrawal of the affected rod

d. Determine appropriate recovery actions

Rev. 26 AOP-001 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 11 of 76 STEP H INSTRUCTIONS J I SECTION A RESPONSE NOT OBTAINED I

DROPPED ROD (Page 2 of 23)

5. Check APP-005-E5, ROD BANKS Borate to clear the alarm using A/B/C/D LO LIMIT - EXTINGUISHED OP-301, Chemical and Volume Control System (CVCS), while continuing with this procedure.

NOTE ITS LCO 3.1.4 restricts operation above 70% power when rods are misaligned greater than ITS limits.

6. Establish Stable Conditions At OR Below 70% Reactor Power As Follows:

a. Check Reactor power - GREATER a. Go To Step 7.

THAN 70%

b. Check APP-005-E2, ROD CONT b. Reduce Reactor AND Turbine SYSTEM URGENT FAILURE -

power to less than or equal EXTINGUISHED to 70% within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> using boration to maintain Tavg within -1.5 to +1.5°F of Tref using OP-301. Chemical and Volume Control System (CVCS).

RCS Boration Quick Checklist.

AND Attachment 1, Turbine Load Adjustment.

Go To Step 7.

c. Reduce Reactor AND Turbine power to less than or equal to 70% within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> using rods and boration to maintain Tavg within -1.5 to +1.5°F of Tref using OP-301. Chemical and Volume Control System (CVCS), RCS Boration Quick Checklist. AND Attachment 1.

Turbine Load Adjustment.

Rev. 26 AOP-O01 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 12 of 76

STEP H INSTRUCTIONS I I SECTION A RESPONSE NOT OBTAINED DROPPED ROD (Page 3 of 23)

7. Notify Load Dispatcher Of The Units Load Capability

8. Check Total Reactor Power Change IF Reactor power is changed

- GREATER THAN 15% IN ANY ONE greater than 15% in any one hour HOUR PERIOD period, THEN perform Step 9.

Observe the NOTE prior to Step 10 and Go To Step 10.

9. Notify Chemistry personnel of the following:

a. A Reactor power change of greater than 15% in a one hour period has occurred

b. Perform sampling as required by ITS SR 3.4.16.2 NOTE

• Quadrant Power Tilt information may be obtained from Group Display QPTR LOG on ERFIS

• FMP-007, Quadrant Power Tilt provides instruction for manual QPTR calculation if ERFIS is unavailable.

10. Monitor Quadrant Power Tilt AND Axial Flux Difference To Ensure Compliance With ITS LCO 3.2.3 and ITS LCO 3.2.4

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 13 of 76 STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED SECTION A DROPPED ROD (Page 4 of 23)

• 11. Determine If Axial Flux Difference (AFD) Should Be Adjusted As Follows:

a. Check APP-005-E2. ROD CONT a. Go To Step 12.

SYSTEM URGENT FAILURE -

EXTINGUISHED

b. Check AFD - WITHIN TARGET BAND b. Perform one of the following:

• IF AFD is below the target band, THEN borate using OP-301, Chemical and Volume Control System (CVCS) , RCS Boration Quick Checklist, while withdrawing Control Rods to restore AFD to the target band.

• IF AFD is above the target band, THEN dilute using OP-301. Chemical and Volume Control System (CVCs) , RCS Dilution Quick Checklist, while inserting Control Rods to restore AFD to within the target band.

WHEN AFD is restored to within the target band, THEN Go To Step 13.

c. Check AFD - Within Operating c. j AFD is outside the Band Operating Band, Power is less than 90% THEN use Attachment 1 to reduce load to less than or equal to 50%

within 30 minutes.

d. Go To Step 13

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 14 of 76

STEP H INSTRUCTIONS f f SECTION A RESPONSE NOT OBTAINED I

DROPPED ROD (Page 5 of 23)

12. Control Reactor Power As Follows:

a. Check AED - OUTSIDE TARGET a. Go To Step 13 BAND

b. Consult with Reactor Engineering to determine expected flux shift for power change

c. Perform EITHER of the following at the request of Reactor Engineering:

• Borate to reduce Reactor power using OP-301.

Chemical and Volume Control System (CVCS).

RCS Boration Quick Checklist, adjust Turbine load to adjust Tavg to within

-1.5 to +1.5°F of Tref using Attachment 1, Turbine Load Adjustment.

OR

• Dilute to raise Reactor power using OP-301, Chemical and Volume Control System (CVCS),

RCS Dilution Quick Checklist, adjust Turbine load to adjust Tavg to within

-1.5 to +1.5°F of Tref using Attachment 1.

Turbine Load Adjustment.

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 15 of 76 STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED SECTION A DROPPED ROD (Page 6 of 23)

13. Confirm Dropped Rod As Follows:

a. Determine if a dropped rod exists by at least ONE of the following:

Quadrant Power Tilt indications - PRESENT

• APP-O05-F3. PR UPPER CH HI FLUX 0EV/AUTO DEFEAT - ILLUMINATED

• APP-O05-F4, PR LOWER CH HI FLUX DEV/AUTO DEFEAT - ILLUMINATED

• APP-005-C3. PR CHANNEL 0EV -

ILLUMINATED

• Power Range Drawer Indications

• Axial Flux Difference indications

• Incore flux map

• Reactor Engineering or I&C determination

• APP-005-A3, PR DROP ROD -

PREVIOUSLY ILLUMINATED

b. Check dropped rod b. HEN determination is determination - COMPLETE complete, THEN Go To Step 14.

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 16 of 76

-tH INSTRUCTIONS J I SECTION A RESPONSE NOT OBTAINED DROPPED ROD (Page 7 of 23)

14. Check Dropped Rod - CONFIRMED Perform the following:

a. Place the ROD BANK SELECTOR Switch in A (Auto) OR M (Manual) as desired.

b. Resume normal rod operations.

c. Go To Section D, Individual Rod Position Indication Failure

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 17 of 76 STEP

INSTRUCTIONS j RESPONSE NOT OBTAINED SECTION A DROPPED ROD (Page 8 of 23)

NOTE This Continuous Action step is designed to assure compliance with ITS LCO 3.1.4 if the rod can NOT be recovered within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

• 15. Check Rod Recovery Status -

IE the rod will NQT be restored COMPLETE to within the alignment limits within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of discovery, THEN perform the following:

a. Verify SDM is within the limits specified in the COLR within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> in accordance with FMP-012, Manual Determination of Shutdown Margin Boron Concentration.

b. Reduce Thermal Power to less than or equal to 70% within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />

c. Verify SDM is within the limits provided in the COLR every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in accordance with FMP-012. Manual Determination of Shutdown Margin Boron Concentration.

d. Notify Reactor Engineering to perform ITS SR 32.l.1 AN2 SR 3.2.2.1 within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />

e. IF the rod can NOT be realigned, THEN within 5 days, complete a Safety Analysis for continued operation with the misaligned rod.

(CONTINUED NEXT PAGE)

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 18 of 76 j STEP H INSTRUCTIONS I I SECTION A RESPONSE NOT OBTAINED I

DROPPED ROD (Page 9 of 23)

15. (CONTINUED)

f. IF the requirements of items a through e can NQ] be achieved, THEN be in Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

16. Notify I&C To Make Repairs As Necessary To Restore Proper Operation Of The Rod Control System

17. Check IRPI for the dropped rod - Perform one of the following:

INDICATES ROD FULLY INSERTED

• IF the rod has been confirmed to be fully inserted by Reactor Engineering, THEN perform Section D for IRPI adjustment prior to continuing with this section.

OR

• IF the rod has been confirmed to be partially inserted, THEN Go To Section B, Immovable/misaligned Rods

Rev. 26 AOP-O01 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 19 of 76 J STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED I

SECTION A DROPPED ROD (Page 10 of 23)

NOTE The rate of rod withdrawal referred to below is in relation to the duration of time over which the rod should be recovered.

NT rod speed.

18. Contact Reactor Engineering To Obtain The Following:

a. Power level at which recovery is to be performed Power Level %

b. Rate at which rod should be withdrawn Rate of Rod Withdrawal

19. Notify Manager - Operations !.

His Designee Of The Following:

a. Current plant conditions

b. Power level required for rod alignment

c. Approval for rod alignment is required prior to continuing

d. Check rod recovery - APPROVED d. Go To Step 39.

20. Check Cause Of Dropped Rod -

WHEN cause is found ANII FOUND CORRECTED corrected. THEN Go To Step 21.

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DROPPED ROD (Page 11 of 23)

21. Determine If The Rod Control System Is Ready For Rod Recovery As Follows:

a. Check APP-005-E2. ROD CONT a. Depress the ROD ALARM RESET SYSTEM URGENT FAILURE -

Pushbutton on the RTGB ANI2 EXTINGUISHED verify APP-005-E2 clears.

b. Verify ROD BANK SELECTOR Switch - IN M (Manual)

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 21 of 76

STEP H INSTRUCTIONS 7 J RESPONSE NOT OBTAINED I

SECTION A DROPPED ROD (Page 12 of 23)

22. Make Preparations For Rod Alignment As Follows:

a. Monitor the highest indicating Power Range NIS Channel

b. Check power reduction -

b. Go To Step 22.d.

REQUIRED

c. Adjust Reactor power level as follows:

• Borate to reduce Reactor power using OP-301, Chemical and Volume Control System (CVCS).

RCS Boration Quick Checklist

• Adjust Turbine load using Attachment 1, Turbine Load Adjustment. steam dumping rate to adjust Tavg to within

-1.5 to +1.5°F of Tref

d. Record the following in the CO Log:

• Time that rod drop occurred

• Power level at which rod will be recovered

• Rate of rod withdrawal to be used

• Core location of dropped rod

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 22 of 76

STEP H INSTRUCTIONS I I SECTION A RESPONSE NOT OBTAINED I

DROPPED ROD (Page 13 of 23)

23. Record The Group Step Counter Reading For The Group Associated With The Dropped Rod I Steps NOTE The P-A Converter is located in the Computer Room in RACK RPI #2 - ROD POSITION DETECTOR & BISTABLE ASSEMBLIES. Key #16 is required to unlock the cabinet door.

24. Determine If The P-A Converter Reading Needs To Be Recorded As Follows:

a. Check dropped rod location - a. Go To Step 25.

LOCATED IN ANY CONTROL BANK

b. Place the DISPLAY Selector Switch in the affected bank position

c. Record the P-A Converter reading for the affected Control Bank Steps

d. Place the DISPLAY Selector Switch in the OFF position

25. Set The Group Step Counter For The Affected Group To Zero

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 23 of 76

STEP_H INSTRUCTIONS J J SECTION A RESPONSE NOT OBTAINED I

DROPPED ROD (Page 14 of 23)

NOTE Key #13 is required to open the Lift Coil Disconnect Panel Door.

26. Place Lift Coil Disconnect Switches For All Rods In The Affected Bank As Follows:

• Dropped Rod - ON Position

• Unaffected Rods - OFF Position

27. Adjust Tavg To Within 1.5 TO +1.5°F Of Tref During Rod Alignment As Follows:

• Adjust Turbine load using Attachment 1. Turbine Load Adjustment OR

• Adjust boron concentration using OP-3O1. Chemical and Volume Control System (CVCS). RCS Boration Quick Checklist

Rev. 26 AOP-O01 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 24 of 76

-IH INSTRUCTIONS I I SECTION A RESPONSE NOT OBTAINED DROPPED ROD (Page 15 of 23)

NOTE

• APP-005-E2. ROD CONT SYSTEM URGENT FAILURE, will illuminate when the rod is moved due to all Lift Coil Disconnect Switches being off in the unaffected group.

• APP-005-A5, ROD BANKS A/B/C/D WITHDRAWN. may illuminate when the rod is moved due to additional counts on the P-A Converter.

• APP-005-F2, ROD BOTTOM ROD DROP, may reflash during rod recovery as the rod is stepping through the bistable setpoints.

28. Align The Affected Rod As Follows:

a. Maintain reactor power less than or equal to 70% in subsequent steps below.

b. traversing the ROD BANK SELECTOR Switch through the AUTO position is required in the next step. THEN Depress AND hold the AUTO ROD DEFEAT Pushbutton

c. Select the affected bank with the ROD BANK SELECTOR Switch

d. IF the AUTO ROD DEFEAT Pushbutton is depressed. THEN release the AUTO ROD DEFEAT Pushbutton

e. Withdraw the rod at the rate specified in Step 18 to the Group Step Counter position recorded in Step 23

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 25 of 76 STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED SECTION A DROPPED ROD (Page 16 of 23)

29. Establish Proper Rod Group Sequencing As Follows;

a. Check Group 1 and Group 2 a. Perform one of the following:

Group Step Counter readings for the affected bank - EQUAL

• the dropped rod was in Group 2, THEN Go To Step 29.c.

OR I the dropped rod was in Group 1, THEN Go To Step 30.

b. Check dropped rod location - b. Go To Step 30.

WAS IN GROUP 1

c. Withdraw the rod one step

d. Insert the rod one step

Rev. 26 AOP-0O1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 26 of 76 STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED SECTION A DROPPED ROD (Page 17 of 23)

30. Return The Rod Control System To Normal As Follows:

a. Place the Lift Coil Disconnect Switches for the affected bank in the ON position

b. j traversing the ROD BANK SELECTOR Switch through the AUTO position is required in the next step. THEN Depress AND hold the AUTO ROD DEFEAT Pushbutton

c. Place ROD BANK SELECTOR Switch in H (Manual)

d. IF the AUTO ROD DEFEAT Pushbutton is depressed, THEN release the AUTO ROD DEFEAT Pushbutton

e. Depress the ROD ALARM RESET Pushbutton on the RTGB

f. Verify APP-O05-E2 clears

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 27 of 76 J STEP H INSTRUCTIONS RESPONSE NOT OBTAINED I

SECTION A DROPPED ROD (Page 18 of 23)

NOTE The P-A Converter is located in the Computer Room in RACK RPI #2 - ROD POSITION DETECTOR & BISTABLE ASSEMBLIES. Key #16 is required to unlock the cabinet door.

31. Determine If The P-A Converter Needs To Be Reset As Follows:

a. Check dropped rod location - a. Observe the NOTE prior to LOCATED IN CONTROL BANK Step 32 and Go To Step 32.

b. Reset the P-A Converter as follows:

1) Place the DISPLAY Selector Switch in the affected bank position

2) While holding the AUTOMATIC-MANUAL Switch in MANUAL, depress the UP PR DOWN Pushbutton the required number of times to return the DISPLAY to the position recorded in Step 24

3) Return AUTOMATIC-MANUAL Switch to AUTOMATIC (spring return)

4) Place the DISPLAY Selector Switch in the OFF position

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 28 of 76

STEP H INSTRUCTIONS I I SECTION A RESPONSE NOT OBTAINED DROPPED ROD (Page 19 of 23)

NOTE Turn on code to access ERFIS ROD BANK SUPERVISION is RODUP.

32. Check ERFIS ROD BANK SUPERVISION Update Bank Position Pulse Function - BANK POSITIONS CORRECT Counters.

Rev. 26 AOP-001 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 29 of 76 STEP H INSTRUCTIONS I I SECTION A RESPONSE NOT OBTAINED DROPPED ROD (Page 20 of 23)

33. Check That Rod Motion Has Perform the following:

Occurred As Indicated By At Least One Of The Following: a. Contact Plant Management to determine need for further

• IRPI indicates rod alignment attempts to recover the dropped rod.

OR

b. Perform The Following To

• Tavg changed during rod Assure Compliance With ITS withdrawal due to rod motion 3.1.4:

1) Verify SDM is within the limits provided in the

• Flux map indicates rod COLR every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in alignment accordance with FMP-012, Manual Determination of Shutdown Margin Boron Concentration.

2) Notify Reactor Engineering to perform ITS SR 32.1.1 AN1 SR 3.2.2.1 within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />

3) IF the rod can NOT be realigned within 5 days.

THEN perform a Safety Analysis for continued operation with the misaligned rod

4) IE the requirements of items 1 through 3 above can NOT be achieved, THEN be in Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />

c. Go To Step 39.

34. Go To Step 39

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 30 of 76 HSTEPHL INSTRUCTIONS I F SECTION A RESPONSE NOT OBTAINED DROPPED ROD (Page 21 of 23)

• • • • • • • • • • • • • • • • • • • • • • • t **t ******

• • • ***************t* ********* ****** * *****

CAUTION Attempts to recover a dropped rod from a Mode 2 initial condition could result in an inadvertent return to criticality.

35. Check Plant Status - MODE 2 Go To Step 37.

NOTE AOP-007 is NQJ applicable for the following step.

36. Check Turbine Status As Follows:

a. Check Turbine - ROLLING a. Go To Step 37.

b. Depress hold the THINK Button

c. Manually trip the Turbine

d. Verify the following valves go closed:

• Turbine Stop Valves

• Governor Valves

• Reheat Stop Valves

• Reheat Intercept Valves

Rev. 26 AOP-OO1 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 31 of 76

STEP H INSTRUCTIONS f RESPONSE NOT OBTAINED I

SECTION A DROPPED ROD (Page 22 of 23)

37. Perform The Following:

a. Fully insert all Control Bank a. Perform the following.

rods

1) IF Control Bank Rods can NOT be inserted, THEN initiate boration of the RCS using OP-3O1. Chemical and Volume Control System (CVCS), RCS Boration Quick Checklist.

2) Contact Reactor Engineering to determine All Rods Out l% Shutdown Boron Concentration.

3) WHEN the required 1%

shutdown concentration has been achieved, THEN trip the Control Rods.

4) Go To Step 38.

b. Fully insert SHUTDONN BANK B rods

c. Fully insert SHUTDOWN BANK A rods

38. Contact I&C and Reactor Engineering to troubleshoot and correct the problem.

39. Implement the EALs

Rev. 26 AOP-O01 MALFUNCTION OF REACTOR CONTROL SYSTEM Page 32 of 76

-tJ-E INSTRUCTI ONS i

SECTION A RESPONSE NOT OBTAINED DROPPED ROD (Page 23 of 23)

40. Review Technical Specifications To Assure All Applicable LCO requirements Have Been Met:

• ITS 3.1.1 - Shutdown Margin (5DM)

• ITS 3.1.4 - Rod Alignment

• ITS 3.1.5 - Shutdown Bank RIL

• ITS 3.1.6 - Control Bank RIL and overlap

• ITS 3.1.7 - IRPI

• ITS 3.2.1 - Fq(Z)

• ITS 3.2.2 - FAh

• ITS 3.2.3 - AFD

• ITS 3.2.4 - QPTR

41. Check APP-005-A3. PR DROP ROD - Momentarily place the DROPPED EXTINGUI SHED ROD MODE Switch on the affected Power Range A Drawer to RESET, AND return to NORMAL.

42. Return To Procedure And Step In Effect

- END -

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01000110305 Task

Title:

Align SI System for Cold Leg JPM No.: 2011-2 NRC JPM B Recirculation KlA

Reference:

006A4.05 3.9/3.8 Oil EA1.11 4.2/4.2 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Plant was at 100% RTP.

A Large Break LOCA occurred.

PATH-i has been implemented.

APP-002-A3, RWST HI/LO LVL has been received with RWST level at 27%

Task Standard: Align the Safety Injection system for cold leg recirculation prior to RWST level lowering to 9%.

Required Materials: EPP-9, Transfer to Cold Leg Recirculation, Revision 33.

General

References:

PATH-i EPP-9 2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1Ñp

Appendix C Job Performance Measure Form ES-C-i Worksheet Handouts: EPP-9 Initiating Cue: The CRS has directed you to implement cold leg recirculation PAW EPP 9.

Time Critical Task: NO Validation Time: 16 minutes SIMULATOR SETUP

1. Reset to IC-807

2. Open SCN: 008_JPM_NRC_B

3. Place simulator in run when directed by the examiner.

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 18 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk )

START TIME:

CAUTION Steps 1 through 24 must be performed without delay to accomplish switchover prior to RWST level reaching 9%.

NOTE

• Foldouts are NOT applicable during the performance of this procedure.

• Functional Restoration Procedures are NOT applicable until after Step 43.

Performance Step: I Check capability to establish recirculation EXISTS (Step 1)

• Establishment of 354 inches in the CV Sump is possible AND

• Establishment of at least one flow path from the CV Sump to the RCS is possible.

Standard: Candidate determines that the CV Sump is greater than 354 inches by observing LI-801 and Ll-802 on the PAM Panel or from the ERFIS computer.

Candidate determines that at least one flow path from the CV Sump to the RCS is possible by observing RTGB indication for the required pumps and valves.

Examiners Note:

Corn ment:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 18 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 2 Reset Safety Injection (Step 2)

Standard: Candidate depresses the Safety Injection reset pushbutton.

Examiners Note: SI can be verified as reset by observing the SI Overridden Train A and Train B status light being illuminated and/or by the EDG WHITE start lights being extinguished.

Examiners Cue:

Comment:

Performance Step: 3 Place the Containment Spray key switch to the OVRD/RESET position (Step 3).

Standard: Candidate places the key switch to the OVRD/RESET position.

Examiners Note: Annunciator APP-002-C1 will be received when this action is performed.

Comment:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 18 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 4 Verify RCPs ALL STOPPED (Step 4)

Standard: Candidate verifies that all of the RCPs have been stopped by observing the RCP status lights above the control switches on the RTGB have the GREEN off indication illuminated.

Examiners Note:

Comment:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 18 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 5 Stop pumps to obtain the following conditions: (Step 5)

• SI Pumps ONE RUNNING

• RHR Pumps - ALL STOPPED

• Charging Pumps ALL STOPPED

• CV Spray Pumps - MAXIMUM ONE RUNNING Standard: Candidate stops one of the SI Pumps by placing the control switch to the STOP position and observing the GREEN off indication illuminated.

Candidate stops both of the RHR Pumps by placing the control switches to the STOP position and observing the GREEN off indications illuminated.

Candidate stops all of the Charging Pumps by placing the control switches to the STOP position and observing the GREEN off indications illuminated.

Candidate verifies that no more than one CV Spray Pump is operating by observing the GREEN off light is illuminated on both CV Spray Pumps.

Examiners Note:

Comment:

NOTE Attachment 1 will locally close valves that have lost power due to an electrical train failure.

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 18 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 6 Close the discharge valves associated with any stopped CV Spray Pump: (Step 6)

• CV Spray Pump A Sl-880A and SI-880B

• CV Spray Pump B Sl-880C and Sl-880D Standard: Candidate determines the CV Spray Pumps that have been secured by observing the GREEN off indication illuminated and closes the associated discharge valves by placing the control switches for the applicable Sl-880 valves to the close position and observing the GREEN close lights illuminated.

Examiners Note: Valves Sl-880A and B are parallel flow paths and both valves must be closed to isolate the path.

Valves Sl-880C and D are parallel flow paths and both valves must be closed to isolate the path.

Comment:

• Performance Step: 7 Close SI PUMP RECIRC valves (Step 7)

• Sl-856A AND Sl-856B Standard: Candidate closes valves Sl-856A and B by placing the control switches to the closed position and observing the GREEN closed indication illuminated (Only one valve is required to be closed for the pathway to be isolated).

Examiners Note: Valves Sl-856A and B are in series and the flow path will be isolated by the closure of either valve.

Booth Operator Cue:

Comment:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 18 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 8 Perform the following: (Step 8)

a. Dispatch an operator to perform Attachment 1

b. Inform the operator performing Attachment 1 of any electrical train failure that has occurred.

c. Dispatch a second operator to perform Attachment 2.

Standard: Candidate will communicate the need and information for Attachments 1 and 2 to be performed locally.

Examiners Cue: Respond that the operators have the attachments and performance has been implemented.

Comment:

Performance Step: 9 Check BIT OUTLET valves ENERGIZED

. SI-870A and SI-870B Standard: Candidate determines that the valves are energized by observing indication available on the RTGB for the valves.

Examiners Note:

Comment:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 18 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 10 Establish CCW flow to the RHR Heat Exchangers as follows:

(Step 10)

a. Start CCW Pumps as necessary to obtain two pumps running.

b. Open CC-749A and B, CCW FROM RHR HX, while continuing with this procedure.

Standard: Candidate will start an additional CCW Pump by placing the control switch to the START position and observing the RED on indication illuminated.

Candidate will open valves CCW-749A and B by placing the control switch to the OPEN position and observing the RED open indication illuminated.

Examiners Note: Valves CCW-749A and B have a long travel time and will take -2 minutes to travel open.

Comment:

Performance Step: 11 Check RWST level Less than 9% (Step 11)

Standard: Candidate determines that RWST level is above 9% by observing Ll-948 and Ll-969 on the RTGB and proceeds to the RNO step. Candidate proceeds to Step 13.

Examiners Note:

Comment:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 18 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 12 Place the key switches for the following valves in the NORMAL position (Step 13)

• SI-862A and SI-862B

• Sl-863A and Sl-863B

• Sl-864A and Sl-864B

• Sl-866A and Sl-866B

• Sl-869 Standard: Candidate will place the control power key switches for the valves in the NORMAL position.

Examiners Note: There is a key switch for each valve listed that is located in the rear of the RTGB on the ECCS Valves Control Power Defeat Panel. An AMBER light above each key switch will illuminate when the key switch is placed in the NORMAL position.

Comment:

Performance Step: 13 Open S1-869, SI HOT LEG HDR valves (Step 14)

Standard: Candidate will open valve SI-869 by placing the control switch to the open position and observing the RED open indication illuminated.

Examiners Note:

Comment:

2011-2 NRCJPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 11 of 18 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 14 Close the following RWST to RHR valves (Step 15)

Sl-862A and Sl-862B Standard: Candidate will close valves Sl-862A and B by placing the control switches to the close position and observing the GREEN close indication illuminated.

Examiners Note: Valves Sl-862A and Sl-862B are in series and requires only one of the valves to be closed to isolate the flow path.

Comment:

2011-2 NRCJPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 12 of 18 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 15 Check the following alarms EXTINGUISHED (Step 16)

• APP-OO1-B7, RHR PMP A COOL WTR LO FLOW

• APP-OO1-C7, RHR PMP B COOL WTR LO FLOW

• APP-002-E1 CV SRY PMP COOL WTR LO FLOW

• APP-002-E5, SI PMP COOL WTR LO FLOW Standard: Candidate determines that all of the annunciators listed are extinguished by observing the annunciator panels on the RTGB.

Examiners Note:

Comment:

Performance Step: 16 Verify at least one RWST to RHR valve closed prior to proceeding to Step 18: (Step 17)

• SI-862A OR SI-862B Standard: Candidate determines that one of the SI-862 valves is cosed by observing the GREEN close indication illuminated for the applicable valve.

Examiners Note:

Comment:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 13 of 18 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 17 Open CV SUMP TO RHR valves: (Step 18)

• Sl-860A and Sl-861A

• Sl-860B and Sl.-861B Standard: Candidate opens valves SI-860A, SI-861A, SI-860B and SI-861B by placing the control switches to the open position and observing that the RED open indication for each valve is illuminated.

Examiners Note:

Comment:

Performance Step: 18 Check at least one train of CV SUMP TO RHR valves OPEN:

(Step 19)

• RHR Pump A Sl-860A and Sl-861A

• RHR Pump B Sl-860B and Sl-861 B Standard: Candidate will select one of the trains and check that the valves supporting that train are open by observing the RED open indication illuminated.

Examiners Note:

Comment:

2011-2 NRCJPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 14 of 18 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 19 Check CV water level Greater than 354 inches (Step 20)

Standard: Candidate determines that CV water level is greater than 354 inches by observing Ll-801 and LI-802 on the PAM Panel or from the ERFIS computer.

Examiners Note:

Comment:

Performance Step: 20 Check CCW FROM RHR HX valve(s) opened in Step 10.b OPEN (Step 21)

• CC-749A

• CC-749B Standard: Candidate determines that both of the valves are open by observing the RED open indication illuminated.

Examiners Note:

Comment:

Performance Step: 21 Check RCS pressure Less than 125 PSIG (Step 22)

Standard: Candidate determines that RCS pressure is less than 125 PSIG by observing Wide Range pressure on the 10CM Subcooling Monitor on the PAM Panel.

Examiners Note:

Comment:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 15 of 18 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 22 Check all of the following completed: (Step 23)

• Attachment 1 Critical Steps

• Attachment 2 Critical Steps

• Any local actions in the following areas:

BIT Room, SI Pump Room, RHR Pit, Pipe Alley Standard: Candidate determines that the attachments and local actions are completed by communicating with the operators assigned to perform the local activities.

Examiners Cue: Inform the candidate that Attachments I and 2 and all required local actions have been completed.

Comment:

• Performance Step: 23 Establish recirculation flow as follows: (Step 24)

a. Verify CV SUMP TO RHR valves for the RHR Pump to be started OPEN:

• RHR Pump A Sl-860A and Sl-861A

• RHR Pump B Sl-860B and Sl-861 B

b. *Verify one RHR Pump - RUNNING Standard: Candidate determines that both of the valves to support the selected train of RHR are open by observing the RED open indication illuminated for the valves.

Candidate starts the selected RHR Pump by placing the control switch to the START position and observing the RED on indication illuminated.

Examiners Note:

Comment:

201 1-2 NRCJPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 16 of 18 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: Cold leg recirculation has been established with one RHR Pump operating prior to the RWST lowering to 9% level.

STOP TIME:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 17 of 18 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM B Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 18 of 18 Form ES-C-I JPM CUE SHEET INITIAL CONDITIONS: Plant was at 100% RTP.

A Large Break LOCA occurred.

PATH-i has been implemented.

APP-002-A3, RWST HI/LO LVL has been received with RWST level at 27%

INITIATING CUE: The CRS has directed you to implement cold leg recirculation lAW EPP-9.

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

Appendix C Page 18 of 18 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: Plant was at 100% RTP.

A Large Break LOCA occurred.

PATH-i has been implemented.

APP-002-A3, RWST HI/LO LVL has been received with RWST level at 27%

INITIATING CUE: The CRS has directed you to implement cold leg recirculation lAW EPP-9.

2011-2 NRC JPM B NUREG 1021, Revision 9, Supplement 1

CONTINUOUSUSE H. B. ROBINSON STEAI1 ELECTRIC PLANT, UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 3 PART 4 END PATH PROCEDURE EPP-9 TRANSFER TO COLD LEG RECIRCULATION REVISION 33 Page 1 of 43

EPP-9, Revision 33 Summary Of Changes (PRR 427144 Various Changed all occurances of increase and decrease to Steps other words with the same meaning. (Generic)

Step 22 Made changes to this RNO step to make it easier RNO to determine the intent of the step. (PRR 427144)

Step 23 Changed this step to make it more evident to the reader that the intent is to ensure personnel are out of the areas that may experience higher radiation levels once recirculation is commenced. (PRR 430444)

EPP-9 Rev. 33 Page 2 of 43

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 3 of 43 Purpose and Entry Conditions (Page 1 of 1)

1. PURPOSE This procedure provides the necessary instructions for transferring the safety injection system and containment spray system to the recirculation mode.

2. ENTRY CONDITIONS When RWST level lowers to less than 27%.

- END -

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• • • • • ***** ******* * *********************** * ****** A***** *** ********* ********

CAUTION Steps 1 Through 24 must be performed without delay to accomplish switchover prior to RWST level reaching 9%.

A * * *** A

• A * * *

• A A * *

• A *

• A A A A A * * *A** * -* ****

• A A -* * *

• NOTE

• Foldouts are NOT applicable during the performance of this procedure.

• Functional Restoration Procedures are NOT applicable until after Step 43.

1. Check Capability To Establish Go To EPP-15. Loss Of Emergency Recirculation - EXISTS Coolant Recirculation.

• Establishment of 354 inches in the CV Surnp is possible AND

• Establishment of at least one flow path from the CV Sump to the RCS is possible

2. Reset SAFETY INJECTION

3. Place The CONTAINMENT SPRAY Key Switch To The OVRD/RESET Position

4. Verify RCPs - ALL STOPPED

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5. Stop Pumps To Obtain The Dispatch the BOP Operator to Following CDnditions: locally trip ANY pump that fails to stop:

• SI Pumps - ONE RUNNING Bus E-1

• RHR Pumps - ALL STOPPED

• SI Pump A - CMPT 21C

• Charging Pumps - ALL STOPPED

• RHR Pump A - CMPT 22A

• CV Spray Pumps - MAXIMUM ONE RUNNING

• CV Spray Pump A - CMPT 1 YA

• SI Pump B - CMPT 22B

• Charging Pump B - CMPT 21B Bus E-2

• SI Pump C - CMPT 23B

• RHR Pump B - CMPT 26B

• CV Spray Pump B - CMPT 25C

• SI Pump B - CMPT 29B

• Charging Pump C - CMPT 2 3A

• DSBus

• Charging Pump A - CMPT 3 4B

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 6 of 43 j STEP H INSTRUCTIONS RESPONSE NOT OBTAINED NOTE Attachment 1 will locally close valves that have lost power due to an electrical train failure.

6. Close The IDISCH Valves IF a valve has failed AND Associated With Any Stopped CV failure is NQ due to an Spray Pump: electrical train failure, THEN Dispatch an Operator to locally

• CV SPRAY PUMP A close the valve.

• SI-880A

• SI-880B

• CV SPRAY PUMP B

• SI-880C

• 51-8801)

7. Close SI PUMP RECIRC Valves

• SI-856A AND

• SI-856B

8. Perform The Following

a. Dispatch an Operator to perform Attachment 1

b. Inform the Operator performing Attachment 1 of any electrical train failure that has occurred

c. Dispatch a second Operator to perform Attachment 2

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9. Check BIT OUTLET Valves -

E the de-energized BIT OUTLET ENERGIZED: Valve is OPEN, THEN dispatch an Operator to locally close the

• SI-870A valve. (Located in BIT Room on top of platform)

AND

• SI-870B

10. Establish CCW Flow To The RHR Heat Exchangers As Follows:

a. Start CCW Pumps as necessary a. i only one CCW Pump is to obtain two pumps running available, THEN open one CCW FROM RHR HX Valve, while continuing with this procedure -

• CC-149A OR

• CC-749B Go To Step 11.

b. Open CC-749A & B. CCW FROM RHR HX, while continuing with this procedure

• 11. Check RWST Level LESS THAN 9%

WHEN RWST level is less than 9%,

THEN perform Step 12.

Go To Step 13.

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12. Verify The Following:

a. SI Pumps - ALL STOPPED

h. CV Spray Pumps - ALL STOPPED

c. CV SPRAY PUMP DISCH Valves -

CLOSED:

• SI-880A

• SI-88O3

• SI-88OC

• SI-8800

13. Place the Key Switches For The Following Valves In The NORMAL Position

• SI-862A

• SI-862B

• SI-863A

• SI-863B

• SI-864A

• SI-864B

• SI-866A

• SI-866E

• SI-869

14. Open SI-869, SI HOT LEC HDR Valve Locally open SI-869. (Located in Pipe Alley at sleeve S-2, top row 2nd from left.)

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15. Close The Following RWST To RHR Verify at least ONE valve is Valves closing/closed.

• SI-862A IF at least one of the valves can NOT be closed, locally close SI-862A OR SI-862B.

(Located in RHR Pit on platform

• SI-862B above RHR PUMP B)

16. Check The Following Alarms -

Establish CCN flow.

EXTINGUI SHED

• APP-OOl-B7, RFIR PMP A COOL WTR LU FLOW

• APP-OOl-C7, RHR PMP B COOL WTR LU PLOW

• APP-002-El. CV SRY PMP COOL WTR LU FLOW

• APP-002-E5. SI PNP COOL WTR LO FLOW

17. Verify At Least One RWST TO RHR Valve CLOSED Prior To Proceeding To Step 18:

• SI-862A OR

• SI-862B

18. Open CV SUMP TO RHR Valves:

• SI-860A

• SI-860B

• SI-861A

• SI-861B

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19. Check At Least One Train Of CV IF at least one train of valves SUMP TO RHR Valves - OPEN: can NOT be opened, THEN Go To EPP-15. Loss Of Emergency

• RHR PUMP A Coolant Recirculation.

• SI-B6OA

• SI-861A

• RHR PUMP B

• SI-86OB

• SI-861B

20. Check CV Water Level - GREATER IF RWST Level is less than 9°fl, THAN 354 INCHES THEN Go To EPP-15, Loss Of Emergency Coolant Recirculation.

WHEN CV water level is greater than 354 inches, THEN Go To Step 21.

21. Check CCW FROM RHR HX Valve(s) WHEN the valve(s) are open, THEN Opened At Step 1O.b - OPEN: Go To Step 22.

• CC-749A IF either CC-749A OR CC-749B can be opened. THEN use the

• CC-749B opposite train RHR Pump in subsequent steps.

Go To Step 22.

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22. Check RCS Pressure - LESS THAN WHEN all of the following are 125 PSIG completed, THEN Go To Step 26:

• Attachment 1 Critical Steps

• Attachment 2 Critical Steps

• Any Local Actions in the following areas:

• BIT Room

• SI Pump Room

• RHR Pit

• Pipe Alley

23. Check All Of The Following WHEN all actions are complete, Completed: THEN Go To Step 24.

• Attachment 1 Critical Steps

• Attachment 2 Critical Steps

• Any local actions in the following areas:

• BIT Room

• SI Pump Room

• RHR Pit

• Pipe Alley

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24. Establish Recirculation Flow As Follows:

a. Verify CV SUMP TO RHR Valves for the RHR Pump to be started - OPEN:

• RHR PUMP A

• SI-86OA

• SI-861A

• RHR PUMP B

• SI-86OB

• SI-861B

b. Verify one RHR Pump - RUNNING

25. Check Both The Following: RCS pressure is greater than 125 psig. THEN perform the

• RVLIS Full Range - STABLE following:

OR RISING

a. Stop the running RHR Pump AND

b. Go To Step 26.

• Core Exit T/Cs - STABLE OR LOWERING RCS pressure is less than 125 psig. THEN perform the following:

a. Stop the running RHR Pump

b. Start the opposite train RHR Pump.

26. Check RWST Level - LESS THAN 9% WHEN RWST level is less than 9%,

THEN Co To Step 27.

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27. Verify The Following: Dispatch the BOP Operator to locally trip ANY pump that fails

a. SI Pumps - ALL STOPPED to stop:

h. CV Spray Pumps - ALL STOPPED

• Bus E-1

c. CV SPRAY PUMP DISCH Valves -

• SI Pump A - CMPT 21C CLOSED:

• CV Spray Pump A - CMPT

• SI-880A 19A

• SI-8803

• SI Pump B - CMPT 22B

• SI-88OC

• Bus E-2

• SI-88OD

• SI Pump C - CMPT 23B

• CV Spray Pump B - CMPT 25C

• SI Pump B - CMPT 29B

28. Close RWST DISCE Valves:

• SI-864A AND

• SI-864B

29. Check RHR Pump Status - RUNNING Go To Step 33.

30. Check CV Pressure - GREATER THAN Go To Step 42.

10 PSIG

31. Check Time Elapsed Since WHEN 73 minutes have elapsed.

Starting Accident - GREATER THAN THEN Go To Step 32.

73 MINUTES

32. Verify Both RHR Pumps - STOPPED

33. Close The RHR HX DISCH Valves:

• RHR-759A AND

• RRR-759B

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34. Check At Least One RWST DISCH WHEN either RWST 015CR Valve is Valve - CLOSED: closed, THEN Go To Step 35.

• SI-864A OR

• SI-864B

35. Check BOTH RHR HX DISCH Valves - WHEN both RHR HX DISCH Valves CLOSED: are closed, THEN Go To Step 36.

• RHR-759A IF either RHR-759A OR RHR-759B can NQI be closed, THEN use the

• RHR-759B opposite train RHR Pump in Step Step 36 and Go To Step 36.

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__STEP_H

36. Establish Recirculation Flow As DWS:

11 FO

a. Check RHR-759A - CLOSED a. Perform the following:

1) Verify CLOSED RHR7S9B.

2) Verify RHR PUMP A is stopped.

3) Open SI-863B, RHR LOOP RECIRC.

4) Close SI-863A, RHR LOOP RE C IRC

5) Start RFIR PUMP B.

6) Go To Step 37.

b. Open SI-863A, RHR LOOP RECIRC. b. Perform the following:

1) Verify RHR-759B CLOSED.

2) Open SI-863B, RHR LOOP RECIRC.

3) Close SI-863A.

4) Start RHR PUMP B

5) Go To Step 37.

c. Start RI-IR PUMP A c. Perform the following:

1) Verify RRR-759B CLOSED.

2) Open SI-863B. RHR LOOP RECIRC.

3) Close S1863A.

4) Start RHR PUMP B

37. Start One SI Pump

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38. Check Both The Following: Perform the following:

a RVLIS Full Range - STABLE a. Stop the running SI Pump OR RISING

b. Stop the running RHR Pump AND

c. Use the opposite train pumps.

a Core Exit T/Cs - STABLE OR LOWERING d. Go To Step 36.

39. Maintain SI Recirculation Flow To The RCS At All Times

40. Check CV Pressure - GREATER THAN Go To Step 42.

10 PSIG

41. Perform The Following:

a. Start ONE CV Spray Pump

b. Open the DISCHARGE valves for the selected CV Spray Pump

• CV SPRAY PUMP A

• SI-880A

• SI-880B

• CV SPRAY PUMP B

• SI-880C a SI880D

• 42. Check Spray Additive Tank Level Verify Spray Additive Tank

- GREATER THAN 0% isolated as follows:

• SI-845A. SAT DISCH, CLOSED

• SI-845B, SAT DISCH, CLOSED

• SI-845C, SAT THROTTLE VALVE, CLOSED

43. Reset SPDS AND Commence Monitoring CSFSTs

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44. Check ANY condition below - IF ANY of the conditions occur, PRESENT THEN Go To EPP-24, Isolation Of Leakage In The RI-IR Pump Pit.

• APP-OO1-D4, RHR PIT A HI-HI LEVEL - ILLuMINATED Go To Step 46 OR

• APP-OO1-O5, RHR PIT B HI-HI LEVEL - ILLUMINATED OR

• EITHER RTGB RHR Pit indication - GREATER THAN 24 INCHES

45. Go To EPP-24, Isolation Of Leakage In The RHR Pump Pit

46. Makeup To RWST Using Supplement P, While Continuing With This Procedure CAUTION The Operator should be sure that cavitation is taking place prior to transitioning to steps that attempt to mitigate screen biorkage. The actions taken are beyond design basis AN should NQI be taken unless warranted.

• 47 Using Available Indications, indication of pump cavitation Determine If RHR Pump Discharge becomes present, THEN Go To Pressure AND Flow Is Stable Step 57.

• PI-6O2A

• PI-6O2B

• FI-6O5

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• 48 Determine CV Sump pH As Follows:

a. Request Chemistry Personnel obtain an RHR sample, while continuing with this procedure

b. Check RHR Sample Results -

b. sample results are AVAILABLE available, THEN Perform step i8.c.

Go To Step 49.

c. Check RHR pH - GREATER TI-IAN c. Go To Attachment 3, 8.5 Increasing CV Sump pH.

• 49 Check CV Pressure - LESS THAN WHEN CV Pressure is less than 4 PSIG 4 psig. THEN perform Step 50.

Observe the NOTE prior to step 51 and Go To Step 51.

50. PerfDrm The Following To Secure CV Spray:

a. Stop the operating CV Spray Pump

b. Verify CV SPRAY PUMP DISCH Valves - CLOSED:

• SI-88OA

• SI-88OB

• SI-880C

• SI-880D NOTE The charging and RCP seal injection lines have been isolated and will not be available for subsequent actions.

51. Determine Status Of Attachment 1 AND 2, Local Cold Leg Recirculation Lineups

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52. Check Entry To This Procedure - Go To Step 54.

FROM PATH-i

53. Reset SPDS AND Return To Procedure And Step In Effect

54. Check RCS Subcooling - LESS THAN Continue operation in cold leg 35°F (55°F] recirculation.

Contact Plant Operations Staff to evaluate long term plant status.

55. Check Elapsed Time Since Event WHEN 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br /> has elapsed, THEN Initiation - GREATER THAN Go To EPP-lO. Transfer To Long 11 HOURS Term Recirculation

56. Go To EPP-lO, Transfer To Long Term Recirculation.

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57. Determine CV Spray Pumps Are Required:

a. Check CV Spray Pump - RUNNING a. Go To Step 60

b. Check CV Pressure - LESS THAN b. IE greater than or equal to 3 4 PSIG CV RECIRC FANs are running.

THI Go To Step 57.c IF less than 3 CV RECIRC FANs are running then Go To Step 60.

c. Verify all CV Spray Pumps -

STOPPED

d. Close CV SPRAY PUMP DISCH Valves on any stopped pump:

1) CV SPRAY PUMP A

• SI-880A

• SI-880B

2) CV SPRAY PUMP B

• SI-880C

• SI-880D

58. Check RHR Pump Discharge Go To Step 60.

Pressure AND Flow - STABLE

• PI-602A

• P1-6023

• FI-605

59. Co To Step 48

60. Check RHR System Alignment - IN Go To Step 32.

PIGGY-BACK MODE

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61. Determine If CV Pressure Can Be Raised:

a. Check CV Pressure - LESS THAN a. Go To Step 62.

3D PSIG

b. Perform Supplement 0 to Raise CV Pressure Using PAHV

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• 62. Operate RHR SI Pumps Intermittently As Follows:

a. Check BOTH Trains of SI AI1J a. Go To Step 63.

RHR Pumps - AVAILABLE

b. Stop ALL SI. CV Spray, RHR Pumps

c. Close CV SPRAY PUMP DISCH Valves on any stopped pump:

1) CV SPRAY PUMP A

• SI-880A

• SI-880B

2) CV SPRAY PUMP B

• SI-880C

• SI-880D

d. Start 1 RHR Pump AND 1 ST Pump on the opposite train to establish flow

e. Check RHR Pump Cavitation -

e. WII RHR Pump cavitation has PRESENT been eliminated, THEN discontinue intermittent operation of the SI RHR Pumps.

Go To Step 63

f. Stop the SI RHR Pump that was started

g. Wait 6 minutes

h. Start 1 RHR Pump D 1 SI Pump on the opposite train to establish flow (CONTINUED NEXT PAGE)

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62. (CONTINUED)

i. Check RHR Pump Cavitation - i. WHEN RHR Pump cavitation has PRESENT been eliminated, THEN discontinue intermittent operation of the SI AND RHR Pumps.

Go To Step 63

j. Continue intermittent operation of the SI RHR Pumps at 6 minute intervals

63. Check CV Pressure - LESS THAN IF cavitation is present, THEN 30 PSIG Go To Step 60.

IF cavitation is NOT present, THEN Go To Step 48.

64. Check RWST Level - GREATER THAN IF cavitation is present, THEN 19% Go To Step 60.

j cavitation is NQ1 present.

THEN Go To Step 48.

65. Stop All SI AND RHR Pumps

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66. Align Valves For SI Injection As Follows:

a. Verify both RHR LOOP RECIRC valves - CLOSED

• SI-863A

• SI-863B

b. Verify both RWST DISCH Valves

- OPEN

• SI-864A

• SI-864B

c. Verify at least one BIT INLET Valve - OPEN

• SI-867A

• SI-867B

d. Verify at least one BIT OUTLET Valve - OPEN

• SI-87OA

• SI-870B NOTE FRP-J.2. Response To Containment Flooding, is HPI applicable during intentional CV Flood.

67. Start One SI Pump

68. Check Either Condition Below Met: WHEN either RWST level lowers below 9% OR CV Water Level

• RWST Level - LESS THAN 9% becomes greater than 420 meLee, THEN Go To Step 69.

OR

• CV Water Level - GREATER THAN 420 INCHES

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69. Stop The SI Pump

70. Align Valves For Piggy-Back Mode As Follows:

a. Verify both RWST DISCH Valves

- CLOSED

• SI-864A

• SI-864B

b. Check BOTH RHR HX DISCH b. IF either RHR-759A OR Valves - CLOSED: RHR-759B can NOT be closed, THEN use the opposite train

• RHR-759A RHR Pump in Step 71.

• RHR-759B

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71. Establish Recirculation Flow As Follows:

a. Check RHR759A - CLOSED a. Perform the following:

1) Verify CLOSED RHR-759B.

2) Verify R}{R PUMP A is stopped.

3) Open SI-863B, RHR LOOP RECIRC.

4) Close SI-863A, RI-JR LOOP REC I RC

5) Start RI-fR PUMP B.

6) Start one SI Pump

7) Go To Step 72.

b. Open SI-863A, RHR LOOP RECIRC. b. Perform tzhe following:

1) Verify RHR-759B CLOSED.

2) Open SI-863B, RHR LOOP RECIRC.

3) Close SI-863A.

4) Start RHR PUMP B

5) Start one SI Pump

6) Go To Step 72.

c. Start RHR PUMP A c. Perform the following:

1) Verify RHR-759B CLOSED.

2) Open SI-863B. RER LOOP RECIRC.

3) Close SI-863A.

4) Start RI{R PUMP B

d. Start one SI Pump

EPP-9 Rev. 33 TRANSFER TO COLD LEG RECIRCULATION Page 27 of 43 j STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED

72. Check RHR Pump Discharge Resume intermittent operation of Pressure AND Flow - STABLE the RHR ANPL SI Pump at 6 minutes between run cycles until

• PI-6O2A discharge pressure M1 flow are stable.

• PI-6O2B Go To Step 74.

• FI-605

73. Go To Step 48

• 74 Check Supplement 0 -. COMPLETED WHEN Supplement 0 is complete, THEN Go To Step 75.

Go To Step 60.

75. Check RHR Pump Discharge Go To Step 60.

Pressure AND Flow - STABLE

• PI-6O2A

• PI-602B

76. Go To Step 48

- END -

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 28 of 43 CONTINUOUS USE ATTACHMENT 1 Attachment 1 (Page 1 of 4)

• ******* ** *t** ** * ******

CAUTION Normal Security and Radiation Protection Procedures are not applicable during the performance of this Attachment.

• t* ****** ***************

• • • • • ************t********

• • • • t*

1. The critical steps of this Attachment should be perform ed as rapidly as possible.

2. Obtain the following equipment as required:

a. Two way radio QE Cell Phone

b. Flashlight NOTE

. SI-856A&B are located between SI Pumps B and C.

. SI-856A&B are rotated clockwise to close.

3. Perform the following valve lineup in the SI Pump Room between SI Pumps B and C:

a. Verify SI-856A, SI PUMP RECIRC Valve - HANDWHEEL CLOSED.

b. Verify SI-856B, SI PUMP RECIRC Valve - HANDWHEEL CLOSED.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 29 of 43 CONTINUOUS USE ATTACHMENT 1 Attachment 1 (Page 2 of 4)

4. IF an electrical train failure has occurred (E-1/E-2 failure),

THEN manually align Spray Pump Discharge valves as follows:

a. IF a Train A failure has occurred, THEN close Spray Pump A valves:

• SI-gsoA, CONTAINMENT SPRAY PUMP A DISCHARGE

• SI-880B. CONTAINMENT SPRAY PUMP A DISCHARGE

b. IF a Train B failure has occurred, THEN close Spray Pump B valves:

• 51-8800. CONTAINMENT SPRAY PUMP B DISCHARGE

• SI-88OD, CONTAINMENT SPRAY PUMP B DISCHARGE NOTE PS-996 is located at the South end on the West wall.

5. In Pipe Alley, open PS-996. RHR/PASS ISOLATION.

6. Notify Control Room that the Critical Steps of Attachment 1 are complete.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 30 of 43 CONTINUOUS USE ATTACHMENT 1 Attachment 1 (Page 3 of 4)

CAUTION The Control Room will be initiating CV Sump Recirculation. This may result in high radiation in the Auxiliary Building.

NOTE The following equipment will be required to perform the steps below:

• Controlled Keys 174 and 175

• Fuse Pullers

7. Isolate the RHR Pump suction as follows:

a. At MCC5 (CMPT6J):

1) Close the breaker for RHR-752A, RHR PUMP A SUCTION.

2) Insert Key #174 in control switch for RHR-752A close the valve.

b. At MCC-6 (C11PT6J):

1) Close the breaker for RHR-752B, RHR PUMP B SUCTION.

2) Insert Key #175 in control switch for RHR-752B M1II close the valve.

8. Deenergize The Charging Pumps As Follows:

a. At 480V BUS E-1, remove the Control Power Fuses for CHARGING PUMP B (CMPT 21B).

b. At 48OV BUS E-2, remove the Control Power Fuses for CHARGING PUMP C (CMPT 23A)

c. At 48OV BUS OS, remove the Control Power Fuses for CHARGING PUMP A (CMPT 33A, Fuse UP)

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 31 of 43 CONTINUOUS USE ATTACHMENT 1 Attachment 1 (Page 4 of 4)

9. Notify Control Room that Attachment 1 is complete.

- END -

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 32 of 43 CONTINUOUS USE ATTACHMENT 2 Attachment 2 (Page 1 of 3)

CAUTI ON Normal Security and Radiation Protection Procedures are not applicable during the performance of this Attachment.

1. The critical steps of this Attachment should be performed as rapidly as possible.

2. Obtain the following equipment as required:

a. Two way radio Q Cell Phone

b. Flashlight NOTE CVC-282 is located above FCV-193OE, STEAM GENERATOR A BLOWDOWN LINE 15 feet above the floor. The blue EOP Tag is fixed to CVC-282 such that it hangs down from the valve near the FCV-1930B operator. The Charging Line enters the CV at Sleeve 17.

3. In Pipe Alley, close CVC-282, CHARGING LINE FLOW ISOL.

4. Notify Control Room that the Critical Steps of Attachment 2 are complete.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 33 of 43 CONTINUOUS USE ATTACHMENT 2 Attachment 2 (Page 2 of 3)

CAUTI ON The Control Room will be initiating CV Sump Recircolation. This may result in high radiation in the Auxiliary Building.

• • • • • • • • • • • • • • • • • ******t*********t**********t************ *********t*******

NOTE

• CVC-297A. B, and C are located in the Northwest corner above Seal Inj Filter shield wall.

• CVC-293A, 293C, 292A, and 295 are located in Northwest corner outside Seal Inj Filter shield wall.

• CVC-295A is located in Northwest: corner above Seal Inj Filters.

• CVC-3O9A and 2O2A are located on West wall adjacent to HCV-121.

5. Verify CLOSED the following valves in the Charging Pump Room:

a. CVC-2glA, RCP A SEAL WATER FLOW CONTROL VALVE.

b. CVC-297B, RCP B SEAL WATER FLOW CONTROL VALVE.

c. CVC-297C. RCP C SEAL WATER FLOW CONTROL VALVE.

d. CVC-293A, SEAL INJECTION FILTER A OUTLET.

e. CVC-293C, SEAL INJECTION FILTER B OUTLET.

f. CVC-292A, SEAL INJECTION FILTER PlC-iS] ISOLATION.

g. CVC-295. SEAL INJECTION FILTER A AND B BYPASS.

h. CVC-295A, SEAL INJECTION FILTERS OUTLET VENT.

i. CVC-3OYA, HCV-121 BYPASS.

j. CVC-202A. HCV-121 OUTLET.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 34 of 43 CONTINUOUS USE ATTACHMENT 2 Attachment 2 (Page 3 of 3)

6. Open the following valves at the IVSW Tank Area Manual Header:

a. IVSW-16, IVSW TO PEN 24, CHARGING LINE ISOLATION.

b. IVSW-16A, IVSW TO PEN 25, 26, & 27, RCPS SEAL INJECTION.

7. Notify Control Room that Attachment 2 is complete.

- END -

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCTJLATION Page 35 of 43 CONTINUOUS USE ATTACHMENT 3 RAISING CV SUMP PH (Page 1 of 5)

CAUTION When applying conservatism in determining the amoun t of NaOH to be added, conservatism should be applied to not exceeding a PH of 10.5 since there

1. Contact Plant Operations Staff To Determine The Amount Of NaOH Needed To Restore PH To Greater Than 8.5

• NaOH Tank Capacity is coriLained in Curve 813.

• 1044 gallons is equal to 0% level.

2. Determine Spray Additive Tank Final Level Using Table Below:

SPRAY ADDITIVE TANK LEVEL CALCULATION Current Level %: = gallons (Curve 8.13) subtract desired gallons -

(Step 1) gallons remaining in tank =

% final level (Curve 8.13)

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCIJLATION Page 36 of 43 CONTINUOUS USE ATTACHMENT 3 RAISING CV SUMP PH (Page 2 of 5)

3. Check Final Level Calculated In Contact Plant Operations Staff Step 2 - GREATER THAN 0% to order NaOH from vender.

WHEN NaOH inventory has been restored to the Spray Additive Tank, ThEfl Go To Step 2.

Co To procedure Main Body. Step 52.

4. Check SI Pump Status - STOPPED Go To Step 12.

5. Cheek Time Elapsed Since Rx WHEN 73 minutes have elapsed.

Tripped - GREATER THAN 73 MINUTES THEN Go To Step 6.

6. Verify Both RHR Pumps - STOPPED

7. Close The RHR HR DISCH Valves:

• RHR-759A

• RHR-759B

8. Check BOTH RHR HX DISCH Valves - WHEN both RHR HX DISCH Valves CLOSED: are closed, THEN Go To Step 9.

• RHR-759A IF either RHR-759A OR RHR-759B can NOT be closed, THEN use the

• RHR-]59B opposite train RHR Pump in Step Step 9 and Go To Step 9.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 37 of 43 CONTINUOUS USE ATTACHMENT 3 RAISING CV SUMP PH (Page 3 of 5)

9. Establish Recirculation Flow As Follows:

a. Check RHR-759A - CLOSED a. Perform the following:

1) Verify CLOSED RHR-759B.

2) Verify RHR PUMP A is stopped.

3) Open SI-863B, RHE LOOP RECIRC.

4) Close ST-863A, RHR LOOP RECIRC.

5) Start RHR PUMP B.

6) Go To Step 10.

b. Open SI-863A, RHR LOOP RECIRC. b. Perform the following:

1) Verify RHR-759B CLOSED.

2) Open SI-863B. RHR LOOP RECIRC.

3) Close SI-863A.

4) Start RHR PUMP B

5) Go To Step 10.

c. Start RHR PUMP A c. Perform the following:

1) Verify RHR-759B CLOSED.

2) Open SI-863B, RHR LOOP RECIRC.

3) Close SI-863A.

4) Start RHR PUMP B

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 38 of 43 CONTINUOUS USE ATTACHMENT 3 RAISING CV SUMP PH (Page 4 of 5)

10. Start One SI Pump

11. Check FI-943, SI COLD LEG HEADER Verify the following:

FLOW - FLOW INDICATED

• SI-867A AND B - OPEN

• SI-87OA A1U2 B - OPEN

• RCS pressure less than 1350 psig

12. Perform The Following:

a. Starc ONE CV Spray Pump

b. Open the DISCHARGE valves for the selected CV Spray Pump

• CV SPRAY PUMP A

• SI-88OA

• SI-880B

• CV SPRAY PUMP B

• SI-88OC

• SI-880D

13. Set Spray Additive Tank Flow On FI-949 To Desired Flow Rate

• 14. Check CV Pressure GREATER THAN Contact Plant Operations Staff OR EQUAL TO 0 PSIG to determine a plan for CV pH control.

Go To Step 16.

15. Check Spray Additive Tank Level WHEN Spray Additive Tank level

- BELOW CALCULATED LEVEL lowers below calculated level, THEN Go To Step 16.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 39 of 43 CONTINUOUS USE ATTACHMENT 3 RAISING CV SUMP PH (Page 5 of 5)

16. Perform The Following To Secure CV Spray:

a. Verify Spray Additive Tank Isolated As Follows:

• SI-845A, SAT DISCH -

CLOSED

• SI-845B, SAT DISCH -

CLOSED

• 51-845G. SAT THROTTLING -

CLO SED

b. Check CV Pressure - LESS THAN b. Go To Procedure Main Body, 4 PSIG Step 49.

c. Stop the operating CV Spray Pump

d. Verify CV SPRAY PUMP DISCH Valves - CLOSED:

• SI-88OA

• SI-88O3

• SI-88OC

• SI-88OD

17. Go To Procedure Main Body. Step 50

- END -

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 40 of 43 ATTACHMENT 4A Continuous Action Steps (Page 1 of 2)

1. IL capability for recirculation can NOT be established, THEN Co To EPP-15, Loss Of Emergency Coolant Recirculation:

- Establishment of 354 inches in the CV Sump is NQI possible OR Establishment of at least one flow path from the CV Sump to the RCS is IIQI possible

11. RWST level is less than 9%. Verify The Following:

a. SI Pumps - ALL STOPPED b CV Spray Pumps - ALL STOPPED

c. CV SPRAY PUMP DISCH Valves - CLOSED:

- SI-880A

- SI-880B

- SI-880C

- SI-BROD

42. JY Spray Additive Tank level is NQI greater than 0%, THEN verify Spray Additive Tank isolated as follows:

- SI-845A, SAT DISCH, CLOSED

- SI-845B, SAT DISCH, CLOSED

- SI-845C, SAT THROTTLE VALVE, CLOSED

44. IF ANY condition below occurs, THEN Go To EPP-24, Isolation Of Leakage In The RHR Pump Pit:

- APP-OOl-D4, RHR PIT A HI-HI LEVEL - ILLUMINATED OR

- APP-OOl-D5, RHR PIT B HI-HI LEVEL - ILLUMINATED OR

- EITHER RTOB RHR Pit indication - OREATER THAN 24 INCHES

47. IL indication of RHR Pump cavitation becomes present, THEN Go To Step 57.

48. )fflfJ5 RHR sample results are available, THEN perform Step 48.c.

49. WHEN CV Pressure Is Less Than 4 PSIC, THEN perform Step 50.

62. RHR Pump cavitation has been eliminated, THEN discontinue intermittent operation of the SI AND RHR Pumps.

74: WHEN Supplement 0 has been completed, THEN check pumps for cavitation.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCIJLATION Page 41 of 43 ATTACHMENT 4A Continuous Action Steps (Page 2 of 2)

Step 3: WHEN NaOH has been received, THEN continue with Attachment 3.

Step 14: I CV pressure drops below 0 psig before required NaOH has been added, THEN stop CV Spray contact staff to determine plan.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCULATION Page 42 of 43 ATTACHMENT 4B Continuous Action Steps (Page 1 of 2)

1. fl capability for recirculation can NQI be established, THEN Go To EPP-l5, Loss Of Emergency Coolant Recirculation:

- Establishment of 354 inches in the CV Sump is NQI possible OR

- Establishment of at least one flow path from the CV Sump to the RCS is IIPT possible

11. WHEN RWST level is less than 9%, THEN Verify The Following:

a. SI Pumps - ALL STOPPED

b. CV Spray Pumps - ALL STOPPED

c. CV SPRAY PUMP DISCH Valves - CLOSED:

- SI-880A

- SI-880B

- SI-880C

- SF8800

42. IF Spray Additive Tank level is NJYL greater than 0%, THEN verify Spray AddiLive Tank isolated as follows:

- SI-845A, SAT DISCH, CLOSED

- SI-845B, SAT DISCH, CLOSED

- SI-845C, SAT THROTTLE VALVE, CLOSED

44. IF ANY condition below occurs, THEN Go To EPP-24, Isolation Of Leakage In The RHR Pump Pit:

- APP-OOl-D4, RHR PIT A HI-HI LEVEL - ILLUMINATED OR

- APP-OOl-D5, RHR PIT B HI-HI LEVEL - ILLUMINATED OR

- EITHER RTGB RHR Pit indication - GREATER THAN 24 INCHES

47. indication of RHR Pump cavitation becomes present, THEN Go To Step 57.

48. WHEN RHR sample results are available, THEN perform Step 48.c.

49. WHEN CV Pressure Is Less Than 4 P51G. THEN perform Step 50.

62. { RHR Pump cavitation has been eliminated, THEN discontinue intermittent operation of the SI AND HER Pumps.

74: WHEN Supplement D has been completed, THEN check pumps for cavitation.

Rev. 33 EPP-9 TRANSFER TO COLD LEG RECIRCIJLATION Page 43 of 43 ATTACHMENT 4E Continuous Action Steps (Page 2 of 2)

Step 3: WHEN NaOH has been received, THEN continue with Attachment 3.

Step 14: IE CV pressure drops below 0 psig before required NaOH has been added, THEN stop CV Spray J5j contact staff to determine plan.

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01000106805 Task

Title:

PZR Pressure Control Malfunction JPM No.: 2011-2 NRC JPM C K/A

Reference:

010A2.02 3.9/3.9 027AA1.01 4.0/3.9 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

• The plant is operating at 50% RTP.

• No equipment is out of service.

• You are the Reactor Operator.

Task Standard: All critical tasks evaluated as SAT.

Required Materials: NONE General

References:

AOP-019, Malfunction of RCS Pressure Control, Revision 16.

Handouts: NONE Initiating Cue: Respond to plant conditions.

Time Critical Task: NO Validation Time: 8 minutes 2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet SIMULATOR SETUP

i. Reset to IC-808.

2. SCN: 008_NRC_JPM_C

3. Place simulator in run when directed by the Chief Examiner.

4. Execute the malfunction when directed by the Chief Examiner.

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 13 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with a check mark)

START TIME:

NOTE Steps I and 2 are immediate action steps.

Performance Step: I Determine if PZR PORVs should be closed (Step 1)

a. Check PZR pressure Less than 2335 PSIG

b. Verify Both PZR PORVs Closed Standard: Candidate determines that PZR pressure is less than 2335 psig by observing PR-444 Pen 1 and/or P1-444, 445, 455, 456 and/or 457.

Candidate determines that both PZR PORVs are closed by observing the GREEN closed indication illuminated on PCV 4550 and 456.

Examiners Note:

Comment:

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 2 Control the normal PZR spray valves and PZR heaters to restore RCS pressure to the desired control band (Step 2)

Standard: Candidate determines that the PZR spray valves are closed by observing the GREEN closed indication on PCV-455A and 455B.

Candidate determines the PZR heater status by observing all of the heaters energized on PZR Control Group and PZR Backup Groups A and B RED on indication illuminated.

Examiners Note:

Comment:

Performance Step: 3 Make a PA announcement for procedure entry (Step 3)

Standard: Candidate makes a PA announcement by using one of the PA handsets and announcing that AOP-019 has been entered.

Examiners Note:

Comment:

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 4 Check PZR Pressure Under operator control (Step 4)

Standard: Candidate determines that PZR pressure is NOT under his control and proceeds to the RNO step.

RNO step states IF PZR pressure approaches a reactor trip setpoint, THEN trip the reactor and Go To PATH-i OR EOP-E-O, Reactor Trip or Safety Injection.

• Low PZR Pressure 1844 psig

• High PZR Pressure 2376 psig

• CT Delta T Variable (TR-41 2)

Examiners Note:

Comment:

Performance Step: 5 Check Pressurizer Pressure Transmitter PT-444 OR PT-445 Failed (Step 5)

Standard: Candidate determines that PT-444 and PT-445 are indicating proper PZR pressure and proceeds to the RNO step and proceeds to Step 7.

Examiners Note:

Comment:

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 13 Form ES-C-I PERFORMANCE INFORMATION Performance Step: 6 Check PC-444J, PZR PRESS Controlling properly in AUTO (Step 7)

Standard: Candidate determines that PC-444J is operating properly in AUTO due to current PZR pressure conditions. PC-444J is indicating at the lower end of its range, attempting to raise PZR pressure back to its setpoint.

Examiners Note:

Comment:

Performance Step: 7 Observe the NOTE prior to Step 11 and Go To Step 11 (Step 8)

Standard: Candidate proceeds to the NOTE prior to Step 11.

Examiners Note:

Comment:

NOTE The response in the following step needs to be based upon plant conditions at entry into AOP-019 to ensure the correct procedure flowpath is taken.

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 8 Check RCS pressure Less than required for current plant conditions (Step ii)

Standard: Candidate determines that PZR pressure is less than the nominal pressure of 2235 psig by observing PR-444 Pen 1 and/or P1-444, 445, 455, 456 and/or 457.

Examiners Note:

Comment:

Performance Step: 9 Check PZR pressure Less than 2205 psig (Step 12)

Examiners Note: Candidate determines that PZR pressure is less than 2205 psig by observing PR-444 Pen 1 and/or P1-444, 445, 455, 456 and/or 457.

Examiners Note:

Comment:

Performance Step: 10 Restore pressure to greater than 2205 psig within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> OR be in Mode 2 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (Step 13)

Standard: Candidate reads and understands the LCO conditions for the present PZR pressure.

Examiners Note:

Comment:

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 11 Check both PZR Spray Valves Closed (Step 14)

• PCV-455A

• PCV-455B Standard: Candidate determines that both PZR Spray valves are closed by observing the GREEN closed indication on PCV-455A and B.

Examiners Note:

Comment:

Performance Step: 12 Observe the CAUTION prior to Step 20 and Go To Step 20 (Step 15)

Standard: Candidate proceeds to the CAUTION prior to Step 20.

Examiners Note:

Comment:

CAUTION With HCV-121, Charging Flow valve closed, throttling seal injection flow will cause the charging pump relief valves to lift.

201 1-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 13 Perform the following: (Step 20)

a. Check CVC-31 1, AUX PZR SPRAY valve - Closed Standard: Candidate determines that CVC-3i 1 is open by observing the RED open indication illuminated on the valve and proceeds to the RNO step.

Examiners Note:

Comment:

Performance Step: 14 Verify CVC-3i 1 control switch is selected to CLOSE (Step 20.a.RNO)

Standard: Candidate determines that CVC-3i 1 control switch is selected to CLOSE by observing the control switch for valve CVC-31 1 on the RTGB.

Examiners Note:

Comment:

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 13 Form ES-C-i PERFORMANCE INFORMATION J Performance Step: 15 IF CVC-3i 1 will NOT close, THEN perform the following (Step 20.a.2.a RNO)

a. Close CVC-460A and CVC-460B, LDTN LINE STOP.

Standard: Candidate closes CVC-460A and B by placing the control switch for the valves in the closed position and observing the GREEN closed indication is illuminated.

Examiners Note: CVC-460A and B are controlled by a single control switch.

Comment:

J Performance Step: 16 IF CVC-31 1 will NOT close, THEN perform the following (Step 20.a.2.b RNO)

b. Verify only one charging pump is running.

Standard: Candidate stops one of the two running charging pumps by placing the control switch on the RTGB to STOP and observing the GREEN off indication is illuminated.

Examiners Note: Candidate may place the charging pump speed controller in manual and lower the pump speed to minimum prior to stopping the pump.

Comment:

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 11 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 16 IF CVC-31 1 will NOT close, THEN perform the following (Step 20.a.2.c RNO)

c. Place running charging pump controller in MAN and adjust to minimum speed.

Standard: Candidate verifies that the charging pump speed controller is in manual by depressing the MAN pushbutton and depresses the DOWN pushbutton until the speed controller indication is at 0%.

Examiners Note:

Comment:

q Performance Step: 17 IF CVC-31 1 will NOT close, THEN perform the following (Step 20.a.2.d RNO)

d. Close HCV-121, CHARGING FLOW valve by slowly adjusting controller HIC-121 to 100% demand while maintaining Charging pump discharge pressure less than 2500 PSIG.

Standard: Candidate closes HCV-121 by rotating the pot in the clockwise direction until the pot will no longer turn and the position indication is at 100%.

Examiners Note: HCV-121 pot is reverse acting 100% indicates that the valve is closed.

Comment:

END OF TASK Terminating Cue: Once these actions are completed, PZR pressure is rising and evaluation of this JPM is complete.

STOP TIME:

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 12 of 13 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM C Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 13 of 13 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: The plant is operating at 50% RTP.

No equipment is out of service.

You are the Reactor Operator.

INITIATING CUE: Respond to plant conditions.

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement 1

Appendix C Page 13 of 13 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: The plant is operating at 50% RTP.

No equipment is out of service.

You are the Reactor Operator.

INITIATING CUE: Respond to plant conditions.

2011-2 NRC JPM C NUREG 1021, Revision 9, Supplement I

CONTINUOUS USE H. B. ROBINSON STEAM ELECTRIC PLANT. UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 3 PART 5 ABNORMAL OPERATING PROCEDURE AOP- 019 MALFUNCTION OF RCS PRESSURE CONTROL REVISION 16 Page 1 of 19

AOP-019 Revision 16 Summary of Changes (PRR 464487)

Various Steps Changed Path-i to Path-i or EOP-E-O in preparation for EOP upgrade. (PRR 464487)

A0P019 Rev. 16 Page 2 of 19

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 3 of 19 Purpose and Entry Conditions (Page 1 of 1)

1. PURPOSE This procedure provides instructions in the event RCS pressure is higher OR lower than required for rurrent plant conditions.

This procedure is applicable in Modes 1. 2, and 3.

2. ENTRY CONDITIONS This procedure may be entered when RCS pressure deviates from the desired control band due to a fault in pressure control components. (AOP-025 covers Instrument Failure)

- END -

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 4 of 19 J STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED I

NOTE Steps 1 and 2 are Immediate Action steps.

1. Determine If PZR PORVs Should Be Closed:

a. Check PZR pressure - LESS a. Verify OPEN at least one PZR THAN 2335 PSIG PORV and associated PORV BLOCK Valve:

• PCV-455C AND RC-536 OR

• PCV-456 AND RC-535 NHEN RCS pressure is less than 2335 psig, ]JjJ perform Step 1.b.

Go To Step 2.

b. Verify Both PZR PORVs - CLOSED b. j any PZR PORV can NQT be closed, THEN close its PORV BLOCK Valve.

2. Control The Normal PZR Spray Valves AND PZR Heaters To Restore RCS Pressure To The Desired Control Band

3. Make PA Announcement For Procedure Entry

4. Check PZR Pressure - UNDER PZR Pressure approaches a OPERATOR CONTROL Reactor Trip Setpoint, THEN trip the Reactor and Go To PATH-i EOP-E-O. Reactor Trip or Safety Injection.

• Low PZR Pressure - 1844 psig

• High PZR Pressure - 2376 psig

• OTAT - Variable (TR-412.)

Rev. 16 AOP- 019 MALFUNCTION OF RCS PRESSURE CONTROL Page 5 of 19 INSTRUCTIONS I I RESPONSE NOT OBTAINED

5. Check Pressurizer Pressure IF PT-44i OR PT-445 FAIL, THEN Transmitter PT-444 OR PT-445 -

Go to AOP-025, RTGB Instrument FAILED. Failure Go To Step 7

6. Go To AOP-025, RTGB Instrument Failure

7. Check PC-444J, PZR PRESS -

Perform the following; OPERATING PROPERLY IN AUTO

a. Place PC-444J, PZR PRESS, in MAN.

b. j PC-444J is operating properly in manual, THEN Go To Step 9.

c. LE PC-444J is ILQ operating properly in manual. ThEN Go To Step 10.

8. Observe the NOTE prior to Step 11 and Go To Step 11

9. Operate PC-444J As Follows:

a. Check PZR SPRAY VALVE a. Restore the affected Controllers - IN AUTO controllers to AUTO.

b. Check PZR Heaters - IN NORMAL b. Place the heaters in the CONFIGURATION desired configuration.

c. Manually adjust PC-444J to maintain PZR pressure.

d. Check PZR pressure - UNDER d. Observe the NOTE prior to CONTROL Step 11 and Go To Step 11

e. Go To Step 29

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 6 of 19 H STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED

10. Control PZR Pressure As Follows:

a. Manually control the PZR SPRAY VALVES to maintain PZR pressure:

• PCV-455A

• PCV-455B

b. Manually control PZR Heaters to maintain PZR pressure:

• PZR HTR BACK-UP GROUP A

• PZR HTR BACK-UP GROUP B

c. Check PZR pressure - UNDER c. Observe the NOTE prior to CONTROL Step 11 and Go To Step 11

d. Go To Step 29 NOTE The response in the following step needs to be based upon plant conditions at entry into AOP-019 to ensure the correct procedure flowpath is taken.

11. Check RCS Pressure - LESS THAN Go To Step 25.

REQUIRED FOR CURRENT PLANT CONDITIONS

12. Check PZR Pressure - LESS THAN Perform the following:

2205 PSIG

• pressure lowers to less than 2205 psig, THEN restore pressure within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> be in Mode 2 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

• Refer to Technical Specification 3.4.1.

• Go To Step 14.

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 7 of 19 STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED I

13. Restore Pressure To Greater Than 2205 PSIG Within 2 HOURS OR Be In Mode 2 Within 6 HOURS

14. Check Both PZR SPRAY VALVES - Perform he following:

CLO S ED

a. Place the affected PZR SPRAY

• PGV-455A VALVE Controller in MAN AND adjust the output to zero.

• PCV-455B

• PCV-455A

• PCV-455B

b. IF the affected valve will NOT close, THEN Go To Step 16.

c. IF the affected valve has closed, THEN observe the CAUTION prior to Step 20 and Go To Step 20.

15. Observe The CAUTION Prior To Step 20 and Go To Step 20

• 16. Perform the following:

a. Dispatch an Operator to Perform Attachment 1, PZR SPRAY VALVE ISOLATION

b. Check PZR Pressure b. PZR Pressure approaches

-APPROACHING 1844 PSIG 1844 psig, THEN Go To Step 17.

WHEN Attachment 1 has been completed, THEN Go To Step 29.

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 8 of 19 J__STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED

17. Perform the following:

a. Check Plant Conditions - IN a. Go To Step 18.

MODE 1 R 2

b. Trip the Reactor

c. Stop the RCP supplying Lhe affected Spray Valve

• RCP B - PCV-455A

• RCP C - PCV-455B

d. Go To PATH-i OR EOP-E-O, Reactor Trip or Safety Injection

18. Stop The ROP Supplying The Affected Spray Valve

• RCP B - PCV-455A

• RCP C - PCV-455B

19. Perform The Following:

a. Check RCP C - RUNNING a. Maintain PZR level between 30% and 40% to provide adequate PZR spray.

b. Go To Step 29

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 9 of 19 j STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED CAUTI ON With HCV-121, CHARGING FLOW Valve closed, throttling Seal Injection Flow will cause the Charging Pump Relief Valves to lift.

• t**t*******************

• • • • • • • • • t***t********t*

• t*t*********t*kt**t***,

20. Perform the foliDwing:

a. Check CVC-311, AUX PZR SPRAY a. Verify CVC-311 Control Switch Valve - CLOSED is SELECTED TO CLOSE.

1) .L CVC-311 is CLOSED, Go to Step 21.

2) IF CVC-311 will NOT Close, THEN perform the following:

a) Close CVC-460A AND CVC-460B, LTDN LINE STOP.

b) Verify only one Charging Pump is RUNNING.

c) Place running Charging Pump Controller in MAN and adjust to minimum speed.

d) Close HCV-l21, CHARGING FLOW Valve by slowly adjusting controller HIC-121 to 100% demand while maintaining Charging Pump Discharge pressure less than 2500 PSIG.

e) Perform Attachment 2, Placing Excess Letdown in Service.

f) Go To Step 29

Rev. 16 AOP-Olg MALFUNCTION OF RCS PRESSURE CONTROL Page 10 of 19 H STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED I

• 21. Check APP-003-F8, PZR LO LVL HTR HN APP-003-F8 is extinguished.

OFF & LTDN SECURE - EXTINGUISHED THEN reset PZR Heaters as follows:

• Place he control switch for PZR HTR CONTROL GROUP to OFF AND return to the ON position.

• Place the control switch for PZR HTR BACK-UP GROUP A to OFF AND return to the AUTO Position.

• Place the control switch for PZR HTR BACK-UP GROUP B to OFF AND return to the AUTO position.

22. Determine Heater Capacity As Follows:

a. Contact Maintenance and Engineering to check PZR Heater capacity

b. Check PZR Heater capacity - b. Go To Step 23.

REDUCED

c. Dispatch an operator to Containment to throttle the Continuous Spray Valves

• RC-524. LOOP C CONTINUOUS SPRAY (PCV-455B BYPASS)

• RC-525, LOOP B CONTINUOUS SPRAY (PCV-455A BYPASS)

d. Refer to ITS LCO 3.4.9

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 11 of 19 f STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED

23. Check PZR Pressure - STABLE R Perform the following:

TRENDING TO REQUIRED VALUE

a. Evaluate primary plant parameters for indications of RCS leakage.

b. i indication of RCS leakage is present, THEN Go To AOP-016. Excessive Primary Plant Leakage.

c. leakage is Q] present, THEN Go To Step 5.

24. Go To Step 29

25. Attempt To Stop Pressure Rise With Heater Control As Follows:

a. Verify ALL PZR Heaters in the OFF position

b. Check PZR pressure - STABLE b. Go To Step 26.

QE. LOWERING

c. Maintain PZR pressure using manual heater control

d. Go To Step 29

26. Check AT between TI-454. PRZR Perform the following:

VAPOR TEMP. and TI-l23, REGEN HX OUTLET TEMP - LESS THAN 320°F a. Reduce pressure using one PZR PORV

• PCV-455C

• PCV-456

b. WHEN PZR pressure is reduced to the desired value, THEN close the open PZR PORV.

c. Go To Step 28.

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 12 of 19 H STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED I

NOTE Supplement K is available for Auxiliary Spray Enhancement if required.

27. Reduce Pressure Using Auxiliary Spray As Follows:

a. Open CVC-311. AUX PZR SPRAY Valve.

b. Verify CLOSED the following valves:

• CVC-310A, LOOP 1 HOT LEG CHG

• CVC-31OB. LOOP 2 COLD LEG CHG

c. WHEN PZR pressure is reduced to the desired value, THEN stop the pressure reduction as follows:

1) Open CVC-31OB 1) Open CVC-310A.

2) Close CVC-311

d. Maintain PZR pressure using manual heater control

28. Check PZR Pressure - STABLE , Go To Step 25.

TRENDING TO REQUIRED VALUE

29. Implement The EALs

30. Contact I&C To Make Repairs To The PZR Pressure Control System

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 13 of 19 j STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED

31. Refer To ITS For Applicable LCOs

• LCD 3.4.11, PZR PORV

• TRM 3.4, PZR Spray AT

• LCO 3.4.4 ANI 3.4.5. RCS Loops

• LCO 3.4.1, RCS Pressure

• LCD 3.4.9, PZR Level

32. Return To Procedure And Step In Effect

- END -

Rev. 16 AOP-O19 MALFUNCTION OF RCS PRESSURE CONTROL Page 14 of 19 CONTINUOUS USE ATTACHMENT 1 PZR SPRAY VALVE ISOLATION (Page 1 of 2)

• • • • • • • • • • • t*** ********************

• • • • t**** ****** ************

CAUTI ON The RCP Bays at: power are High Radiation Areas.

NOTE

. Entry to high temperature environments is controlled by AP-020, Heat Stress Control Procedure.

. All actions of this attachment are performed locally in the Containment.

1. IF PCV-455A is the affected SPRAY VALVE, THEN Go To Step 2.

IF PCV-455B is the affected SPRAY VALVE, THEN Go To Step 3.

NOTE

• A flashlight adjustable wrench will be required to perform the step below.

. All valves listed below are located in RCP Bay B at the top of the wall separating the Pump Bay from the PZR Cubicle.

2. Perform the following to isolate PCV-455A:

a. Close RC-525. LOOP B CONTINUOUS SPRAY (PCV-455A BYPASS).

b. Close IA-3800, PCV-455A BOOSTER ISOLATION

c. Close IA-3627. IA TO PCV-455A I/P ISOLATION

d. Disconnect the Swagelock Fitting at the PCV-455A Booster for the tubing connection to PCV-455A diaphragm vent the air from the top of the PCV-455A diaphragm.

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 15 of 19 CONTINUOUS USE ATTACHMENT 1 PZR SPRAY VALVE ISOLATION (Page 2 of 2)

NOTE

• A flashlighL A adjustable wrench will be required to perform Lhe step below.

• All valves listed below are located in PZR Cubicle on the side of the PZR opposite the wall separating the Pump Bay from the PZR Cubicle.

3. Perform the following to isolate PCV-455B:

a. Close RC-524, LOOP C CONTINUOUS SPRAY (PCV-455B BYPASS).

b. Close IA-3799. PCV-455B BOOSTER ISOLATION

c. Close IA-3798. PCV-455B I/P ISOLATION

d. Disconect the Swagelock Fitting at the PCV-455B Booster for the tubing connection to PCV-455B diaphragm ANL vent the air from the top of the PCV-455B diaphragm.

4. Notify the Control Room that Attachment 1 has been completed.

- END -

Rev. 16 AOP-0l9 MALFUNCTION OF RCS PRESSURE CONTROL Page 16 of 19 j STEP H INSTRUCTIONS RESPONSE NOT OBTAINED CONTINUOUS USE ATTACHMENT 2 PLACING EXCESS LETDOWN IN SERVICE (Page 1 of 2)

1. Verify CC-739. CCW FROM EXCESS LTDN HX - OPEN

2. Verify CVC-389. EXCESS LTDN DIV.

- IN THE RCDT POSITION

3. Open CVC-387, EXCESS LTDN STOP CAUTI ON i Excess Letdown Heat Exchanger outlet temperature exceeds 195°F, THEN damage could result.

• • • • • • • • • • t**tt**t********t******************************W****************

4. Slowly open HIC-137, EXCESS LTDN FLOW

5. Check Excess LetdDwn Heat IF temperature exceeds 195°F, Exchanger Outlet Temperature - THEN perform Step 6.

GREATER THAN 195° F Observe the NOTE prior to Step 7 and Go To Step 7.

6. Reduce Flow From Excess Letdown Using HIC-l37 To Maintain Temperature Less Than 195°F.

NOTE PZR level will rise if total Charging flow exceeds total Letdown flow AND RCP Seal Leakoff flow.

7. Check PZR Level - RISING PZR Level begins to rise.

THEN perform SLops 8 AND 9.

Go To Step 10.

8. Verify The Running Charging Pump

- AT MINIMUM SPEED

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 17 of 19 H STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED I

CONTINUOUS USE ATTACHMENT 2 PLACING EXCESS LETDOWN IN SERVICE (Page 2 of 2)

9. Contact Chemistry To Purge The PZR Liquid Sample Line With Full Flow To The VCT Using CP-003, Systems Sampling Procedure

• 10 Check PZR Level - GREATER THAN IF PZR level rises to 63%, THEN 63% perform Step 11.

Go To Step 12.

11. Reduce PZR Level Below 63% Perform the following:

a. Be in Mode 3 with the Trip Breakers open within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

b. Be in Mode 4 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

• 12 Check PZR Level - APPROACHING 91% IF PZR level approaches 91%.

THEN Go To Step 13.

Go To Step 14.

13. Trip The Reactor And Go To PATH-i OR EOP-E-0, Reactor Trip or Safety Injection

14. Inform The CRS That Excess Letdown Is In Service AND That Continuous Action Steps Are In Effect

- END

Rev. 16 AOP-0l9 MALFUNCTION OF RCS PRESSURE CONTROL Page 18 of 19 ATTACHMENT 3A Continuous Action Steps (Page 1 of 1)

MAIN BODY

1. WHEN RCS pressure is less than 2335 psig. THEN perform Step 1.b

4. IF PZR Pressure approaches a Reactor Trip Setpoint, THEN trip the Reactor and Go To PATH-i OR EOP-E-0. Reactor Trip or Safety Injection.

5. IF PT-444 OR PT-445 FAIL. THEN Go to AOP-025. RTCB Instrument Failure.

12 IF pressure lowers to less than 2205 psig, THEN restore pressure within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> OR be in Mode 2 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

16 PZR Pressure approaches 1844 psig, THEN Go To Step 17.

21. WH1 APP-003-F8 is extinguished. ThEN reset PZR Heaters as follows.

ATTACHMENT 2 7 IF PZR Level begins to rise. THEN perform Steps 8 9.

10. IF PZR Level rises to 63%, perform Step 11.

12. IF PZR Level rises to 91%, IIIEN Go To Step 13.

Rev. 16 AOP-019 MALFUNCTION OF RCS PRESSURE CONTROL Page 19 of 19 ATTACHMENT 3B Continuous Action Steps (Page 1 of 1)

MAIN BODY

1. WHEN RCS pressure is less than 2335 psig. THEN perform Step 1.b

4. IF PZR Pressure approaches a Reactor Trip Setpoint, THEN trip the Reactor and Go To PATH-i OR EOP-E-0. Reactor Trip or Safety Inj ection -

5. IF PT-444 OR PT-445 FAIL, THEN Go to AOP-025, RTGB Instrument Failure.

12. IF pressure lowers to less than 2205 psig. THEN restore pressure within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> OR be in Mode 2 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

16. IF PZR Pressure approaches 1844 psig, Th Go To Step 17.

21. WHI APP-003-F8 is extinguished. ThEN reset PZR Heaters as follows.

ATTACHMENT 2

7. IF PZR Level begins to rise, THEN perform Steps 8 AND 9.

10. IF PZR Level rises to 63%, THEN perform Step 11.

12. IF PZR Level rises to 91%, Go To Step 13.

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01045100401 Task

Title:

Startup, Parallel, and Load the Main JPM No.: 2011-2 NRC JPM D Generator K/A

Reference:

045 A4.02 2.7/2.6 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objecti ve for this Job Performance Measure will be satisfied.

Initial Conditions:

• Plant startup is in progress lAW GP-005, Power Operation.

• Turbine is operating at 1800 RPM.

• GP-005, Revision 102, is completed up to Step 8.4.2.

Task Standard: Pickup turbine load to at least 20 MWe to prevent the actuati on of the Generator Lockout.

Required Materials: GP-005, Power Operation, Revision 102 General

References:

GP-005, Power Operation, Revision 102 2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Handouts: GP-005, Power Operation, Revision 102 Initiating Cue: The CRS has directed you to place the voltage regulator in service and place the unit on line lAW GP-005, Section 8.4, starting at Step # 8.4.2.

Time Critical Task: NO Validation Time: 10 minutes SIMULATOR SETUP

1. Reset to 10-809

2. Open SCN: 008_i i_2_JPM_D

3. Place simulator in run when directed by the examiner.

201 1-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 12 Form ES-C-I PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk *

)

START TIME:

• Performance Step: I CLOSE the Exciter Field Breaker (Step 8.4.2)

Standard: Candidate will close the Exciter Field Breaker by placing the control switch to the CLOSE position and observing the RED closed indication illuminated and the GREEN open indication extinguished.

Examiners Note:

Comment:

NOTE: The Exciter Field Breaker may trip if Generator voltage exceeds 22.0 Ky.

• Performance Step: 2 PLACE the Voltage Regulator in service as follows:

(Step 8.4.3.a)

a. Slowly ADJUST Generator voltage, as indicated on GEN Phase A Phase B VOLTS OR ERFIS point ELV2800 A, to 22.0 Ky using the Manual Field Current Adjuster.

Standard: Candidate adjusts the generator voltage by placi ng the Field Current Adjuster control switch to the RAISE posi tion and monitors the generator voltage, not to exceed 22.0 Ky.

Examiners Note: The Field Current Adjuster control switch has the word MANUAL directly under the applicable control swit ch.

Examiners Cue:

Comment:

2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 12 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 3 PLACE the Voltage Regulator in service as follows:

(Step 8.4.3.b)

b. IF the Regulator Balance Meter does NOT indicate 0,

THEN NOTIFY engineering for further guidance prior to proceeding.

Standard: Candidate observes the Regulator Balance mete r at 0 and N/As the step.

Examiners Note:

Comment:

NOTE: Placing the VOLTAGE REGULATOR in the TEST position disables the voltage followers. The time spent with the Volt age Regulator in the TEST position should be minimized.

Performance Step: 4 PLACE the Voltage Regulator in service as follows:

(Step 8.4.3.c)

c. PLACE VOLTAGE REGULATOR in AUTO.

Standard: Candidate places the Voltage Regulator control switch from the OFF to the AUTO position and observes the RED on indication illuminated and the GREEN off indication extinguis hed.

Examiners Note:

Comment:

2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 12 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 5 PLACE the MAIN GENERATOR Synchroscope key switch in the GEN NORTH position (Step 8.4.4)

Standard: Candidate places the MAIN GENERATOR synchroscope key switch in the GEN NORTH position.

Examiners Note: This will energize the synchronizing circuit and cause the synchroscope to move.

Comment:

NOTE: If Generator voltage is less than Switchyard voltage then adjusting the VOLTAGE ADJUSTER in the raise direction will cause % DIFF VOLTS to lower. If Generator voltage is greater than Switchyard voltage then adjusting the VOLTAGE ADJUSTER in the raise direction will cause % DIFF VOLTS to rise.

Performance Step: 6 ADJUST the % DIFF VOLTS to zero using the VOLTAGE ADJUSTER (Step 8.4.5)

Standard: Candidate determines whether the generator voltage is less than or greater than switchyard voltage by observing the % DIFF VOLTS meter and adjusts the difference in voltage to zero.

Examiners Note:

Comment:

2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 12 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 7 ADJUST Turbine speed using the REF DOWN and/or REF UP AND GO pushbuttons so that the Synchroscope is rotating SLOWLY in the FAST DIRECTION (Step 8.4.6)

Standard: Candidate adjusts the speed of the turbine to ensure that the synchroscope is rotating slowly in the FAST direction.

Examiners Note: This adjustment normally requires that the turbine speed be raised several RPM above 1800 RPM to have the synchroscope rotating properly.

Comment:

CAUTION The assumptions in EC 63785 allow Reactor Power above 10% for short period s of time as long as it is maintained < 15%. Maintaining Reactor Power < 10% prior to Genera tor synchronizing ensures a margin to this limit.

The AT-POWER Reactor Trips are automatically unblocked as Reactor power or Turbine load is raised above 10% (Permissive circuit P-7). Conversely, these trips are autom atically blocked as Reactor power and Turbine load are lowered below the P-7 setpoint. The AT-PO WER Reactor Trips are:

- Pressurizer High Level

- Pressurizer Low Pressure

- Reactor Coolant Low Flow

- Reactor Coolant Pump Bus Undervoltage and Underfrequency

- Reactor Coolant Pumps tripped 2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 12 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 8 VERIFY Tavg is at the high end of the 547°F to 551°F band AND Reactor Power is 6% to 10% (Step 8.47)

Standard: Candidate determines that the reactor is at 8% power as indicated on Recorder NR-45 and/or the Power Range Nuclear Instrument drawers.

Examiners Note:

Comment:

NOTE The sequence of actions necessary to synchronize the unit to the grid is TIME CRITICAL. The RO, BOP, and Feedwater Operator shall verbally rehearse the actions of the following step and coordinate their actions at all times while synchronizing to the grid and loading the unit. It would be beneficial to have a dedicated stop watch operator to ensure contingency actions are not missed.

To reduce the magnitude of the transient when synchronizing to the grid, Tavg should be greater than 547° F and rising.

Experience has shown that a Control Rod withdrawal of 10 steps is optimum.

Performance Step: 9 SYNCHRONIZE the Main Generator to the 230 KV Grid as follows: (Step 8.4.8.a)

a. WITHDRAW Control Rods to raise Tavg Standard: Candidate is instructed that the additional operator will ensure that the control rods are withdrawn as directed in the procedure.

Examiners Cue: The additional operator will perform the actions necessary to control reactor power and SIG levels as directed by the procedure.

Comment:

2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

U Appendix C Page 8 of 12 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 10 SYNCHRONIZE the Main Generator to the 230 KV Grid as follows: (Step 8.4.8.b)

b. WHEN the synchroscope is rotating SLOWLY in the FAST DIRECTION AND reaches a point equivalent to 5 minutes before the 12 oclock position, THEN CLOSE the NORTH OCB BKR 52/9. Time Standard: Candidate will ensure that the synch roscope is rotating slowly in the FAST direction and close the NORTH OCB 52/9 by placing the control switch to the CLOSE position and observing the RED closed indication illuminated and the GREEN open indication extinguished.

Examiners Note: The EH Panel indication will shift from Speed Control to Load Control when the OCB is closed.

The synchroscope will indicate 12 oclock (midnight) when the OCB is closed.

Comment:

CAUTION If GV#i (GLU) and GV#3 (GLL) are not off their closed seats (Closed position lights EXTINGUISHED) within 1 minute of closing the NORTH OCB BKR 52/9 when paralleling to the Grid, a Generator Lockout will occur. Turbine Control may be placed in TURB MAN and GV UP and GV DOWN pushbuttons used as necessary IF OPER AUTO is not available or to pick up additional load.

IF it is necessary to re-open a Generator Output OCB, the THINK BUTTON must be held in the DEPRESSED position until the OCB indicates open.

2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 12 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 11 SYNCHRONIZE the Main Generator to the 230 KV Grid as follows: (Step 8.4.8.c)

c. IF GV#i (GLU) OR GV#3 (GLL) remain CLOSED, THEN within 30 seconds, ADJUST Turbine load UP (NOT to exceed 70 MWe) until GV#1 (GLU) AND GV#3 (GLL) are off their closed seats (Closed position lights EXTINGUISHED.)

Standard: Candidate will determine that GV#1 and GV#3 indicate close d by the GREEN closed lights illuminated for the valve positions.

Candidate is expected to perform one of the following actions to pick up at least 20 MWe load and not exceed 70 MWe load:

1. Raise the setter by depressing the REF UP pushbutto n

and GO pushbutton to raise the turbine load with the turbine controls in lOPER AUTO.

2. Depress the TUR MAN and GV UP pushbutton to raise the turbine load.

Examiners Note: With the turbine in OPER AUTO, the candidate may choose to raise the loading rate to greater than 1%/MIN, NOT to exceed 5%IMIN.

With the turbine in TUR MAN, the candidate may depr ess the GV UP and FAST action pushbuttons simultaneousl y to raise load.

Comment:

2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 12 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: Main Generator has been synchronized to the grid with the minimum load picked up.

STOP TIME:

2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page ii of 12 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM D Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature:

Date:

2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

Appendix C Page 12 of 12 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• Plant startup is in progress lAW GP-00 5, Power Operation.

• Turbine is operating at 1800 RPM.

• GP-005, Revision 102, is completed up to Step 8.4.2.

INITIATING CUE: The CRS has directed you to place the vol tage regulator in service and place the unit on line lAW GP

-005, Section 8.4, starting at Step # 8.4.2.

201 1-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1

I Appendix C Page 12 of 12 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS

• Plant startup is in pro gress lAW GP-005, Po

• Turbine is operating wer Operation.

at 1800 RPM.

• GP-005, Revision 10 2, is completed up to St ep 8.4.2.

INITIATING CUE:

The CRS has directed you service and place the un to place the voltage regulator in it starting at Step # 8.4.2. on line lAW GP-005, Section 8.4, 2011-2 NRC JPM D NUREG 1021, Revision 9, Supplement 1 I

Progress Energy Conous H. B. ROBINSON STEA M ELECTRIC PLANT PLANT OPERATING MA NUAL VOLUME 3 PART 3 GP-005 POWER OPERATION REVISION 102 CAUTION OPS-NGGC-I 306 defin es planned changes in I0% Power as a Major Reactor Power Reactivity Manipulatio n (RI).

GP-005 Rev. 102 Page 1 of 107

SUMMARY

OF CHANGES PRR 462937 GP-005, Revision 102 STEP REVISION COMMENTS Changed GP-006 to GP-006-1. GP-006 is being cancelled

. (PRR 8.3.13.d(3) 462936)

GP-005 I Rev. 102 Page 2of107

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE 4

2.0 REFERENCES

4 3.0 RESPONSIBILITIES . 10 4.0 PREREQUISITES 10 5.0 PRECAUTIONS AND LIMITATIONS 11 6.0 SPECIAL TOOLS AND EQUIPMENT 19 7.0 ACCEPTANCE CRITERIA 19 8.0 INSTRUCTIONS 20 8.1. Initial Conditions 20 8.2. Warming Up the Secondary 26 8.3. RoIling the Turbine 34 8.4. Electrical Startup and Loading of Generator 56 8.5. Raising Load from 30% to 100% Load 81 9.0 RECORDS 96 10.0 ATTACHMENTS 96 Attachment 10.1 Reactor Power Ascension Indicator Log 97 Attachment 10.2 Power Change Tracking Log 98 Attachment 10.3- Venting the Feedwater Heaters 99 Attachment 10.4 Draining the Steam Headers 101 Attachment 10.5 Feedwater HeaterAlignment

. 103 Attachment 10.6 Turbine Recommended Start-Up and Loading Times 106 Attachment 10.7- EHAVP Cards 107 GP-005 Rev. 102 Page 3 of 107

1.0 PURPOSE To provide the initial conditions, precautions, and instructions to permit a safe, normal Plant Start-up from MODE 2 to MODE 1 at 100% power.

Included in this procedure are instructions for warming up the Secondary, rolling the Turbine, loading the Generator, and raising Turbine load.

RI REACTIVITY EVOLUTION

2.0 REFERENCES

2.1. NRC, INPO and Other Related Industry Documents

1. Westinghouse Turbine/Generator Operating Instructions and Load Curves

2. Areva Technical Document 64-9047834-000, Non-B&W Power Operat ions Guidelines

3. SOER 94-01, Conservative Decision Making

4. SOER 90-003, Nuclear Instrument Miscalibration

5. SOER 90-2, Nuclear Fuel Defects (Recommendation 2C)

6. SOER 99-01, Loss Of Grid, Recommendation 2A, Fleet Item 3

7. SOER 07-1, Reactivity Management, Recommendation #1, Standards and Expectations

8. OE25981, Maximum Allowable Short Term Power Limit Exceeded FoUow ing Return to 100% Power Due to Personnel Error (Calvert Cliffs)

9. SOER 96-2, Design and Operating Considerations for Reactor Cores (Recommendation 1)

10. SOER 10-1, Large Power Transformer Reliability (Replaces SOER 02-3)

11. 0E28665, Tube Leaks in Low Pressure Feed Water Heater (Arkansas Nuclear One) 2.2. Nuclear Generation Group (NGG) Procedures and Documents

1. OPS-NGGC-1 306, Reactivity Management Program

2. ADM-NGGC-0006, Online EOOS Models for Risk Assessment

3. OPS-NGGC-1 308, Plant Status Control

4. EGR-NGGC-1 020, Conduct of Reactor Engineering and Nuclear Fuels Management

5. NFP-NGGC-0029, Reactivity Manipulation Plan Development GP-005 Rev. 102 Page4of107

F 2.3. Robinson Plant Procedures and Documents

1. UFSAR Section 4.2.1.2.2, Clad Stress Limits

2. Improved Technical Specifications (ITS)

3. PLP-100, Technical Requirements Manual (TRM)

4. Station Curve Book

5. OP-001, Reactor Control and Protection System

6. OP-301, Chemical and Volume Control System (CVCS)

7. OP-401, Auxiliary Heating System

8. OP-405, Main and Reheat Steam System

9. OP-406, Steam Generator Blowdown/Wet Layup System

10. OP-407, Heater Drains and Vents

11. OP-408, Miscellaneous Drains System

12. OP-501, Condensate System

13. OP-502, Gland Seal Steam and Drain

14. OP-503, E.H. Fluid System

15. OP-504, Condenser Air Removal

16. OP-505, Hydrogen Seal Oil System

17. OP-506, Turbine Lube Oil

18. OP-507, Generator Hydrogen System

19. OP-509-1, Condensate Polishing System

20. OP-601, DC Supply System

21. OP-603, Electrical Distribution

22. OP-903, Service Water System

23. OP-904, Circulating Water System N

GP-005 Rev. 102 Page 5of107

[

2.3 Robinson Plant Procedures and Documents (continued)

24. OP-91 6, Secondary Chemical Addition

25. OP-917, Secondary Sampling System

26. OP-923, Containment Integrity

27. GP-002, Cold Shutdown to Hot Subcritical at No Load Tavg

28. GP-003, Normal Plant Startup from Hot Shutdown to Critical

29. GP-006-1, Normal Plant Shutdown From Power Operation to Hot Shutdown

30. OST-OlO, Power Range Calorimetric During Power Operation (ERFIS)

31. OST-202, Steam Driven Auxiliary Feedwater System Component Test

32. OST-206, Steam Driven Auxiliary Feedwater Pump Flow Test

33. OST-551-1, Turbine Valve Test

34. OST-551-2, Turbine Trip Functional Test (Quarterly During Power Operation)

35. OST-553, Turbine Mechanical Overspeed Trip Test

36. QST-554, Turbine Bearing Oil System and E-H Control System Hydraulic Components Test

37. OST-623, Fire Barrier Penetration Seal Inspection

38. OST-920, Operations Cold Shutdown Test Procedure

39. EST-067, Intermediate Range Detector Setpoint Determination

40. EST-052, Operational Alignment of Process Temperature Instrumentation

41. EST-105, Post-Refueling Power Escalation Procedure

42. RNPD/89-4365, Special Directive for Limitations for ON-LINE

43. RNPD/89-4329, Coordination of Voltage Schedules and MVAR Generation at Robinson Plant GP-005 Rev. 102 I Page 6 of 107

L 2.3 Robinson Plant Procedures and Documents (continued)

44. FMP-009, Power Distribution Control

45. PLP-037, Conduct of Infrequently Performed Tests or Evolutions and Pre Job Briefs

46. PM-I 66, Blowdown of Feedwater and Steam Flow Transmitters, SIG Level Transmitters, and SIG Feedwater Flow Bartons.

47. OMM-O0I-12, Minimum Equipment List and Shift Relief

48. OST-020, Shiftly Surveillances

49. OST-021, Daily Surveillances

50. OST-022, Weekly Surveillances

51. OST-023, Monthly Surveillances

52. RCP-131, Actions for Startups, Shutdowns, and Greater Than or Equal to 15 Percent Reactor Power Changes

53. OMM-048, Work Coordination and Risk Assessment

54. AOP-006, Turbine EccentricityNibration

55. AOP-007, Turbine Trip Below P-8

56. APP-005, NIS & Reactor Control

57. APP-008, SW, CW & Turb. Gen. Aux.

58. FMP-007, Quadrant Power Tilt

59. OMM-001-9, Equipment Tagging

60. Control Wiring Diagrams (CWD) B-190628:

a. Sheet 670, Quenching Valves FCV-I 596 and FCV-I 597

b. Sheet 732, Bearing Oil Lift Pump

c. Sheet 855, Turbine Annunciation

61. SORMC-NUC-030, Robinson Plant Voltage Support Coordination GP-005 Rev. 102 Page 7 f 107

2.4. Adverse Condition Reports (ACRs), Nuclear Condition Reports (NCRs) and Other Related Documents

1. ACR 93-284, Power Range Nuclear instrumentation indication Error

2. ACR 93-348, PLP-037 Not Performed for GP-005 Prior to Plant Startup

3. ACR 93-312, Main Electrical Generator Meggar Very Low and Unstable (due to moisture in Iso-Phase Bus Duct)

4. ACR 94-01276, Steam Line Drains Found Out of Position

5. ACR 94-00310, Turbine Governor Valve Leakage

6. CR 95-02020, TM Log Not Reviewed Prior to Exceeding 2% Power

7. Operability Determination 95-015 Rev. 2, PZR Spray Valve PCV-455A

8. CAPS Project CR 95-02365, Incorporation of OD 95-015 Recommendations

9. CR 96-00002, Control of Instructional Aids

10. NCR 329164, Cylinder Heating Steam Issues

11. NCR 329223, Unplanned Turbine Trip and AOP-007 Entry

12. NCR 364964, Governor Valve #2 (GRU) Failed to Open

13. OPEX 332815, 0E28665, Tube Leaks in Low Pressure Feed Water Heater

14. NCR 364929, Plant Startup Delays Due to Main Steam Valve Seat Leakage

15. NCR 364940, R-11 and SRNI Spike While Closing OCB Disconnects

16. OPEX 388359, SOER 10-1, Large Power Transformer Reliability (Replaces OPEX 189399 for SOER 02-3)

17. NCR 433833, Turbine Would Not Increase Speed > 1020 RPM GP-005 Rev. 102 Page 8of107

2.5. Modifications (MODs), Engineering Changes (ECs) and Other Related Documents

1. ESR 96-00201, Efficiency Improvement

2. ESR 98-00395, Cycle 20 Core Reload

3. ESR 99-00372, Use high content graphite packing in Condensate Pump

4. ESR 00-00208, FIS-1446 Replacement

5. EC 47069, Main Steam N-16 Monitors

6. EC 47139, HP Turbine Rotor Replacement

7. EC 47152, Ultrasonic Feedwater Flow Measurement

8. EC 47160, NSSS and BOP Analysis to Support Appendix K Uprate

9. EC 47162, Set-Points, Uncertainty Caic Changes For Appendix K Uprate

10. EC 47208, NR-45 Recorder Replacement

11. EC 53914, Turbine Generator TSI Upgrade

12. EC 67727, Installation of Replacement Feedwater Heaters 4A and 4B

13. EC 69831, LPTurbine Steam Path Replacement

a. EC 74557, EC 69831 Child EC #2 performed during RFO-26

14. EC 63785, Change P-7 to P-8 Relative to Turbine Trip vs. Reactor Trip

15. EC 71678, Auxiliary Transformer Replacement GP-005 Rev. 102 Page 9 of 107

3.0 RESPONSIBILITIES

1. Operations is responsible for the overall performance and coordination of this procedure.

2. Reactor Engineering is responsible for the development and distribution of the Reactivity Management Plan as described in OPS-NGGC-1 306, Reactivity Management Program, and EGR-NGGC-1 020, Conduct of Reactor Engineering and Nuclear Fuels Management.

4.0 PREREQUISITES

1. GP-003 is complete as necessary with Reactor power stabilized at 5x1 0 to 8 amps; or the Reactor has remained critical following a Secondary 5x10 side (Turbine) shutdown.

GP-005 Rev. 102 Page lOof 107

5.0 PRECAUTIONS AND LIMITATIONS

1. Planned/scheduled power changes will have a Risk Assessment performed lAW OMM-048, Work Coordination and Risk Assessment, and ADM-NGGC-0006, Online EOOS Models for Risk Assessment.

2. The Reactor trips on Low Primary Coolant Flow in one of three loops and Turbine Trip are automatically unblocked as nuclear power is raised above 40 percent (P-8).

3. Failure of two of four Power Ranges results in a false P-b signal preventing operation of Source Range instruments.

4. The AT-POWER Reactor Trips are automatically unblocked as Reactor power or Turbine load is raised above 10% (permissive circuit P-7).

Conversely, these trips are automatically blocked as Reactor power and Turbine load are lowered below the P-7 setpoint. The AT-POWER Reactor Trips are:

Pressurizer High Level Pressurizer Low Pressure Reactor Coolant Low Flow Reactor Coolant Pump Bus Undervoltage and Underfrequency Reactor Coolant Pumps tripped

5. Before transferring to Automatic Rod Control, Tavg should be adjusted to within 0.5° F of the reference temperature to avoid a transient following the transfer.

6. During MODE 1 and MODE 2, all Rod Position Indicators and Nuclear Power Range Channels should be periodically monitored for indications of control rod misalignment and abnormal power tilts.

7. LR-477, Wide Range S/G Levels, should be used for trending of Steam Generator levels only when in manual level control.

8. The Feedwater Regulating Valves FCV-478, FCV-488, FCV-498, and Rod Control should be placed in MANUAL when switching Turbine first stage pressure channels. The Feedwater Regulating Valves FCV-478, FCV-488, FCV-498, should be placed in MANUAL when switching steam flow channels, or feedwater flow channels.

GP-005 Rev. 102 Page 11 of 107

5.0 PRECAUTIONS AND LIMITATIONS (continued)

9. During start-up and loading of the Turbine, S/G water level is very unstable and has a tendency to swell. SIG levels should be maintained from 40% to 50% on narrow range level indication for better control. The wide range and narrow range tend to disagree slightly when there is a transient level condition. Wide range level indication should be used to observe which direction the level is moving. If the narrow range level approaches the High or LO-LO Level trip point, Turbine loading should be stopped until SIG level recovers. Wide swings in Feedwater Regulating Valve positions, in the open or closed direction, should be avoided, as this can cause water level to shrink or swell out of control. Sustained Turbine operation at less than 5%

of rated load should be avoided.

10. For Turbine startups and scheduled load changes, the heatup and loading rates specified in Curves 7.8, 7.9, and 7.10 should be followed.

11. Power Ramp Rate Limits are restricted after core fuel movement to 3.5%/hr from 50% to 100% power. During subsequent power escalations, this ramp limit may apply depending on the maximum power level achieved and length of operation at that power level. Specifically, this requirement can be removed for reactor power levels below a given power level P (50 % < P < 100 %), provided that the plant has operated at or above power level P for at least 72 cumulative hours out of any seven day operating period following the shutdown. (ESR 98-00395, SOER 90-2, Rec. 2C and UFSAR 4.2.1.2.2)

12. Fuel is considered preconditioned at a specific power level when that power level (or higher) has been maintained for at least 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. When the fuel is preconditioned, the maximum Ramp Rate Limit is 30% per hour.

When operating with a fuel defect the following conservative ramp rates will be implemented: for power escalations from power levels below 90% power with conditioned fuel, the ramp rate will be restricted to 10% per hour below 90% power and 3.5% per hour above 90% power. Additional Ramp Rate Limits or other operating conditions, such as elevated letdown, may be implemented as a result of a fuel defect.

13. Following a significant (10 ppm or more) change in RCS Boron concentration, additional PZR heaters should be energized. This will permit opening of the PZR spray valves and allow the Boron concentration between the PZR and the RCS loops to equalize.

GP-005 Rev. 102 Page12of107

5.0 PRECAUTIONS AND LIMITATIONS (continued)

14. The RCS Design Basis Document states that the PZR Spray Valves are designed to prevent PZR pressure from reaching the lift setpoint of the PZR PORVs following a step reduction of 10% of full power under automatic Reactor control during normal plant operations. Normal loading and unloading is 5% of full power per minute. Operability Determination 95-015 Rev 2 identifies that when one PZR Spray Valve is out of service, step changes should be limited to 5% of full power to reduce the potential for challenging the PZR PORVs. (CAPS Project CR 95-02365)

15. Exhaust hood temperature should not be allowed to exceed 175°F with exhaust hood spray out of service, If the temperature cannot be reduced to less than 175°F, the unit should be shutdown and the trouble corrected.

The maximum exhaust hood temperature permitted is 250°F for a maximum of 15 minutes. A manual Turbine trip is required if any Exhaust Hood indication shows a valid temperature of 250°F or greater for greater than 15 minutes. (EC 69831, EC 74557, APP-008)

16. The Turbine Oil Coolers should maintain oil temperature leaving the bearings within the limits of the Expected Bearing Oil Return and Metal Temperature. section of OP-506.

17. During power ascension, Gland Seal Pressure should be maintained in the normal operating band (3 to 6 psig) as indicated on the Gland Seal Header Pressure (P1-4004, P1-i 382 or ERFIS Pt GSP2O95A). This may require throttling GS-36, MANUAL GLAND SEAL DUMP to maintain pressure.

18. The EH Turbine Control should be maintained in the IMP IN position when changing power and during turbine valve tests. However, should plant conditions dictate, power changes may be made in the IMP OUT position.

The EH Turbine Control should be maintained in IMP OUT whenever stable plant conditions exist.

19. The OVERSPEED PROTECT CONTROL LIGHT on the Turbine EH Display Panel may be illuminated when operating at low power conditions (< 10%)

and may result in intermittent alarms on APP-009-E2, GOV CAB MONITOR TROUBLE. This will clear after the unit is synchronized to the grid and power> 10%.

20. The SPEED CHAN light on the Turbine EH Display Panel may flash at turbine speeds less than 600 rpm and may result in intermittent alarms on APP-009-E2, GOV CAB MONITOR TROUBLE.

GP-005 Rev. 102 Page 13of107

5.0 PRECAUTIONS AND LIMITATIONS (continued)

21. The Unit 2 generator should be operated lAW the SORMC-NUC-030, Robinson Plant Voltage Support Coordination, VAR loading should be coordinated with Unit 1.

22. The OPEN indication (green light) for OCBs 52/8 and 52/9 requires all three phases to be OPEN. The CLOSED indication (red light) could be illuminated with one or two phases closed, however if there is pole disagreement for 3 cycles a trip signal to the breaker is generated.

(SER 8-97)

23. Steam shall not be used to raise the Main Turbine speed above 600 rpm until RCS TAVG is 547°F.

24. During power ascension, all indications of reactor power level should be monitored and compared at 10% intervals. Indications such as core zT and Turbine First-Stage Pressure should be compared to NI indications and Continuous Calorimetric Program percent power. If all indications do not agree within 5% of each other, then Reactor Power should be stabilized, OST-OlO performed, and plant management contacted for further instructions. (SOER 90-003, Recommendation Ia)

25. The NI channel which has the highest indication on NR-45 should be monitored to provide for conservative action by the operator. Approximately every 10% rise in power, the operator should verify the NR-45 indication is in agreement with the power range drawer within 3%. Work requests should be written to correct inaccurate indications. (SOER 90-003)

26. Management approval, in ALL CASE I activities, is defined as approval by the Management Designated Monitor (MDM), who shall be senior to the SM and designated by the Plant General Manager. It is not intended for the MDM to compromise the responsibilities of the SM, which include maintaining the plant in a safe operating condition at all times and the authority to shut down the plant as necessary to ensure safe operations.

GP-005 Rev. 102 Page 14 of 107

5.0 PRECAUTIONS AND LIMITATIONS (continued)

27. ITS SR 3.4.16.2 requires that RCS dose equivalent 1-131 specific activity be verified <0.25 jtCi/gm within 2 to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after every thermal power change of>15% in any one hour period. E&C will perform these actions lAW procedure RCP-131.

Every time the power level of the Reactor is changed 15% or more in any one hour, E&C shall be notified of the power change, including the time started and the expected duration of the transient. Do not wait until after an hour of changing power before notifying E&C. Additionally, E&C shall be notified when the transient is completed.

A power level change shall be defined for sampling purposes as an absolute value of 15%/hr in one direction only, (i.e. 95% to 80% 15%,

or 95% to 85% to 90% = 10%). This includes controlled changes, runbacks, transients, and trips that result in changes greater than 15%

in any one hour period.

Tracking of Notifications and Sample Results should be performed using Attachment 10.2, Power Change Tracking Log, or a similar method of Electronic Tracking such as Autolog (CR 23734). The intent is to ensure timely notification of power changes and operations verification that sampling has been performed and the results verified within the required sampling frequency of 2 to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

28. The following applies to the Exciter air temperature:

Maximum allowable Exciter air discharge temperature is 80°C as indicated on the RTGB.

Maximum allowable Exciter air inlet temperature is 125°F(52°C) as indicated on ERFIS points TGT331OA and TGT331IA.

Exciter air discharge temperature should be maintained between 48°C and 60°C as indicated on the RTGB with the unit in service.

Even though there are no vendor recommended minimum temperature limits, temperatures below 48°C should be avoided with the unit in service to avoid condensation buildup.

Temperatures above 60°C should be avoided as this may reduce the life of the electrical components.

Exciter air temperatures exceeding any of these values with the unit in service should be investigated by Engineering.

GP-005 Rev. 102 Page 15of107

I 5.0 PRECAUTIONS AND LIMITATIONS (continued)

29. Smoke may come out of the stuffing box when starting a Heater Drain Pump. This is a normal occurrence with the graphite packing that has been installed.

30. Main Steam Line N-16 Monitor R-24 is not compensated for power levels below 40% Reactor power. GPD indication will initially be low and rise as power is raised to 40%. Recorder trends below 40% power are only reliable when constant reactor power has been maintained during the trend.

31. The ultrasonic feedwater flow instrumentation may provide a calorimetric determination of power between 15% and 100% power.

32. When changing from IMP IN to IMP OUT or IMP OUT to IMP IN relatively large swings (10 MW) in thermal power may occur.

33. It may be difficult to maintain the Reactor critical due to rapid changes in Xenon following a large power change. If the Reactor can NOT be stabilized due to operating limitations of the reactivity controlling systems, the Reactor shall be shutdown. Time spent with the Reactor critical and the secondary (turbine) secured should be minimized. If at any time the Reactor cannot be maintained stable and critical, then the Reactor shall be shutdown lAW GP-006-1. (SOER 07-1, Recommendation #1)

34. When withdrawing control rods in MODES I and 2, RPI should be maintained within the ITS alignment limits. Rod motion should be stopped and adjustments made, as allowed, to maintain indication within the limits.

ERFIS should be used to monitor RPI.

35. When above 98% power, reactivity should not be changed by more than one method at a time (control rods, turbine steam demand, or boron dilution), to prevent exceeding 100% power. (OPEX 266297)

GP-005 Rev. 102 Page 16ofI07

5.0 PRECAUTIONS AND LIMITATIONS (continued)

36. As described in OPS-NGGC-1 306 and NFP-NGGC-0029, Reactor Engineering will provide a Reactivity Management Plan for all planned power changes of 10% or greater. This plan is useful to the Control Room team so that they can anticipate the response of the Reactor to Control Rod insertions and withdrawals and RCS borations and dilutions.

The Reactivity Management Plan should be considered a Living Document that the Reactor Engineers can and will update as actual core response is observed and recorded. The Reactivity Management Plan is guidance for the anticipated response of the Reactor Core given the known conditions at the time the plan is developed. The Reactivity Management Plan is not an approved procedure.

The Control Room Operators must exercise prudent, conservative, judgment and decision making while changing and adjusting Reactor parameters and NOT rely solely on the Reactivity Management Plan for expected Reactor response.

37. EC 63785 makes the following assumptions concerning Reactor Power control and operations while preparing to latch the Turbine and synchronizing the Generator to the grid:

a. Reactor Power should be maintained below 10% Power by highest indication while using just the Steam Dumps to control Reactor Power and Temperature.

b. Reactor Power may be raised above 10% Power but not to exceed 15% Power while preparing to latch the Turbine and synchronize the Generator to the grid.

c. Extended Steam Dump operation (greater than approximately six to twelve hours) to maintain Reactor Power >10% is outside the scope of EC 63785.

d. Simulator validation of EC 63785 shows that the Steam Dumps Controls must stay in the Steam Pressure mode until Reactor Power is 20% power. This is necessary to ensure proper Steam Dump operation if a Turbine Trip were to occur at power levels below 20%

power. The amount of pressure change required in Turbine jst Stage Pressure may not be enough to give an arming signal when the Turbine is less than 20% loaded and Steam Dump Controls are in the Tavg Mode.

GP-005 Rev. 102 Page 17 of 107

5.0 PRECAUTIONS AND LIMITATIONS (continued)

38. OP-405 for the Main Steam System contains the following information concerning the HP Turbine Cylinder Heating System (NCR 329164):

a. Pl-1380A, HP TURBINE STEAM TO PCV-1380 and P1-I 381A, HP TURBINE STEAM TO PCV-1381 INDICATOR indicate the HP turbine outlet pressure. P1-i 380B, HP TURBINE STEAM RETURN FROM PCV-1 380 and P1-1381 B, HP TURBINE STEAM RETURN FROM PCV-1381 INDICATOR indicate pressure in the Cylinder heating gland. Gland pressure must be slightly above that of the HP outlet.

Therefore, P1-i 380B should read higher than P1-i 380A AND PI-1381B should read higher than P1-i 381A. If water is present where the rotor exits the gland, it is an indication that cylinder heating is NOT adequate and that differential pressure should be raised.

b. Cylinder Heating Steam pressure may NOT be stable with Turbine loads less than 100% therefore, adjustments should be made only after consulting with RES.

39. The shell sides of the Feedwater Heaters are vented to remove non-condensable gasses. This is done to improve heater efficiency and to reduce the potential for corrosion and corrosion related failures. The following precautions apply while venting the Feedwater Heaters (OPEX 329815, OE28665):

a. Depending on the vent line configuration and length, it is possible for hot water to exit the vent prior to the venting of steam and non-condensable gasses.

b. Venting of Feedwater Heaters is performed starting with the highest pressure heaters, 6A and 6B, and then working down to the lowest pressure heaters.

c. Venting of individual Feedwater Heaters to atmosphere should be done only after the shell side pressures are above 5 psig. This will ensure non-condensable gasses are forced out.

d. Feedwater Heaters 3A & B and 4A & B may have a partial vacuum at low loads. It may be necessary to wait until Unit Load is >30% power for the closure of the respective start-up vents to ensure these heaters have a positive shell pressure.

GP-005 Rev. 102 Page 18 of 107

I 5.0 PRECAUTIONS AND LIMITATIONS (continued)

40. Normally 2 boilers are operated to maintain gland seal pressure. Depending on the wear condition of the Main Turbine Gland Seals and the Auxiliary Steam (AS) System loads, it may be necessary to run all three Aux. Boilers to maintain stable Gland Seal pressure while Aux. Steam is supplying Gland Seal Steam. Loss of Gland Seal pressure could lead to a loss of Main Condenser Vacuum. Loss of Main Condenser Vacuum would result in a loss of temperature control when using the Steam Dumps. This will complicate the Turbine start-up and cause unnecessary distractions while various plant systems are in manual.

41. APP-005-D6, t Flux Warning I Status, and APP-005-E4, Flux Alarm, are driven by the ERFIS Computer System. IF ERFIS is Out of Service (QOS) then these alarms are also OOS. FMP-009, Power Distribution Control, provides the necessary guidance when these alarms are OOS.

42. APP-005-F3, PR Upper CH Hi Flux Dev IAuto Defeat, and APP-005-F4, PR Lower CH High Flux Dev IAuto Defeat, are driven by the signals from the Detector Current Comparator sections of the Miscellaneous Control and Indication Panel located above the Power Range N-44 drawers. If the Reactor flux profile is significantly above or below zero (Reactor midplane),

it is possible for a secfion to show that all channels are below 50% when actual Reactor Power is >50% power. FMP-007, Quadrant Power Tilt, and ITS SR 3.2.4.1 give the necessary guidance for these conditions.

6.0 SPECIAL TOOLS AND EQUIPMENT N/A 7.0 ACCEPTANCE CRITERIA N/A GP-005 Rev. 102 Page 19 of 107

I I Section 8.1 Page 1 of 6 INIT 8.0 INSTRUCTIONS 8.1. Initial Conditions NOTE: This section has been screened lAW PLP-037 criteria and determined N/A to PLP-037.

1. This revision has been verified to be the latest revision NOTE: Steps in the remainder of this section are not sequence dependent and can be performed in any order.

2. VERIFY the Condensate Polishing System is in service lAW OP-509-1 to support current Plant conditions.

3. VERIFY AMSAC is in service lAW OP-001 section for Placing AMSAC in Service.

4. VERIFY the following lineups are completed:

OP-407: Heater Drains and Vents Checklist OP-408: Miscellaneous Drains System Valve Checklist OP-501: Condensate System Checklist OP-503: E. H. Fluid System Valve Checklist OP-504: Condenser Air Removal Valve Checklist OP-505: Hydrogen Seal Oil System Valve Checklist OP-506: Turbine Lube Oil System Checklist OP-507: Generator Hydrogen System Checklist OP-904: Circulating Water System Valve Checklist OP-916: Secondary Chemical Addition Valve Checklist OP-917: Secondary Sampling System Checklist GP-005 Rev. 102 Page 20 of 107

Section 8.1 Page 2 of 6

5. VERIFY all Steam Generator water levels are 40 50%.

6. VERIFY Station Battery C AND its DC Distribution System are in service lAW OP-601.

NOTE: The ITS Bases states that the 31 day frequency on a STAGGERED TEST BASIS results in testing each pump once every 3 months.

7. IF OST-202 was NOT completed within the STAGGERED TEST BASIS of SR 3.7.4.2, THEN PERFORM OST-202.

Completion date of latest OST-202:

8. IF OST553 is scheduled, THEN ENSURE OST-551-2, Overspeed Trip Test is performed before OST-553.

9. IF either of the following applies, THEN SCHEDULE OST-553:

This power escalation is following a refueling AND OST-553 was j /

NOT performed during the shutdown.

While shutdown, maintenance has been performed on the / /A Mechanical Overspeed Trip Mechanism. ,)_111,

10. VERIFY that the cooling fans for the following Electrical System components are aligned as follows:

a. The following dampers are full open unless Plant conditions justify otherwise:

Isolated Phase Bus Heat Exchanger Fan A suction damper /

Isolated Phase Bus Heat Exchanger Fan B suction damper GP-005 Rev. 102 Page21of107

I Section 8.1 Page 3of6 INIT 8.1.10 (Continued)

b. Control switches for these components should be placed in the AUTO position unless Plant conditions justify otherwise:

Isolated Phase Bus Heat Exchanger Fan A Isolated Phase Bus Heat Exchanger Fan B Main Transformer A Heat Exchanger 43-1 43-2 Main Transformer B Heat Exchanger 43-1 43-2 AU Main Transformer C Heat Exchanger 43-1 AU:

43-2 AUT1/L NOTE: When the Auxiliary Transformer Control Switch 43M is in AUTO, one bank of cooling fans should be running.

The 43C switch will always be in either the Lead Cooler #1 or #2 Position. The As Found position is documented for configuration control purposes.

c. The switches for the Auxiliary Transformer Cooling Fans should be placed in the following position unless Plant conditions justify otherwise:

43C Switch Position COOLEFkZI, Aux Transformer Cooling Fans Control Switch 43M AUT4 GP-005 I Rev. 102 Page 22 of 1071

Section 8.1 Page 4 of 6 INIT NOTE: To fully close the disconnects the operator must continue to crank them closed after they make contact with the buss bar until they make a 90° turn that locks them into the closed position.

The Plant Transmission Activity Coordina tor (PTAC) is responsible for scheduling thermography of the 230KV Swit chyard Disconnects once all disconnect operations are complete. (NCR 364940)

CAUTION There will be a static discharge as the 230K V disconnects are approaching the closed position. This discharge will cause spiking of the Source Range Nuclear Instruments and various Radiation Monitoring Instruments.

(NCR 364940)

11. PERFORM the following actions in the 230K V Switchyard:

a. INFORM the Control Room to expect spiking on Source Range NIS and various RMS instruments whil e operating 230KV Disconnects.

b. VERIFY CLOSED the following disconnects:

North OCB 52/9 South Disconnect (Unit side)

South OCB 52/8 North Disconnect (Unit side)

12. INFORM the Unit #2 PTAC to schedule therm ography of the 230KV Switchyard name of person contacted)

13. VERIFY RCS temperature is being maintaine d between 547°F AND 551°F using one of the following (N/A the method NOT used): (ACR 94-01276)

Controlling RCS Temperature section of OP-4 05 Steam Dump operation in STEAM PRESS mod e

14. IF Condenser Vacuum has NOT been estab lished, THEN PERFORM OP-504 section for Placing the Con denser Air Removal System in Service.

GP-005 I Rev. 102 I Page 23 of 107

Section. 8.1 Page 5 of 6

15. IF the Reactor has remained critical following a Seco INIT ndary side (Turbine) shutdown, THEN REVIEW the Tempora ry Equipment Modification Log to verify that conditions do NOT exist that would jeopardize the operability of ITS or TRM required equi pment.

(CR 95-02020)

16. VERIFY that the Plant Risk Profile has been updated lAW -3y)

OMM-048 for the start-up activities.

17. VERIFY the following:

a. OMM-001-12 MODE I Checklist is completed.

b. MODE I required SRs identified in the following tests are completed:

OST-020 OST-021

. OST-022 OST-023

18. VERIFY the following: (NFP-NGGC-0029 and SOE R 96-2, Recommendation 4)

a. Reactor Engineering has provided technical guidance lAW NFP-NGGC-0029.

b. A Reactor Engineer is present in the Control Room to support the power rise.

19. IF the reactor will be maintained critical with the seco ndary (turbine) shutdown, THEN CONTACT Reactor Engi neering to provide technical guidance. (SOER 07-1, Recomme ndation #1)

A/Ic Engineering Contact (Print name)

GP-005 Rev. 102 Page 24 of 107j

Section 8.1 Page 6 of 6

20. IF NOT previously energized, THEN VERIFY the Feed INIT water Ultrasonic Flow Measurement (FWUFM) system is ENER GIZED lAW OP-403 section for Startup Of FWUFM System.

21. CONTACT Engineering to determine if a Turbine Valve/

Trip Test is reqy)red at 1800 rpm Req uireY No ngineering Con/act (Print name). (le one)

22. CONTACT Engineering to determine if EST-105 is require d.

fl 4 C1 L .C 4C A Test Required Yes Engineering Contact (Print name) (Circle one)

GP-005 Rev. 102 Page 25 of 107

Section 8.2 Page 1 of 8 INIT NOTE: All steps shall either be initialed when performed or, if the procedure intent is met by existing Plant conditions, the step shall be marked N/A and initialed by the SM. If the safe, efficient operation of the Plant so dictates, the steps may be performed simultaneously or out of sequence 8.2. Warming Up the Secondary NOTE: The remainder of this procedure has been determined to involve PLP-037 Case II activities.

1. A Management Designated Monitor (MDM) shall be assigned AND shall give permission to perform this evolution as documented by having performed the Pre-Job briefing.

Management Designatd Monitor signature BEGIN CRITICAL STEPS NOTE: Maximizing Letdown promotes additional mixing of RCS boron concentration AND allows for larger primary water addition rates.

2. IF additional letdown flow is desired, THEN PERFORM the following lAW OP-301 section for Charging and Letdown Operations with Normal Pressurizer Level:

START additional Charging Pumps as necessary.

PLACE additional letdown orifice in service.

3. ENERGIZE all available Pressurizer heaters to equalize boron concentration in the Pressurizer.

- PZR HTR CONTROL GROUP

- PZRHTRBACK-UPGROUPA

- PZRHTRBACK-UPGROUPB oiL.

GP-005 Rev. 102 Page 26 of 107

Section 8.2 Page 2 of 8 INIT NOTE: The Point Of Adding Heat (POAH) is that power level identified by NO control rod motion and:

- If MTC is negative, then SUR will be LOWERING

- If MTC is positive, then SUR will be RISING

- Onset of RCS temperature rise, Onset of PZR pressure rise, Onset PZR level rise.

- Reduction in AUTO Charging Pump speed demand.

- Rising indication of AUTO Steam Dump demand on PC-464B, Steam Header Pressure, when Steam Dumps are being used for RCS Temperature Control.

- Small rise in Steam Generator Steam flow.

CAUTION Startup Rate shall not exceed 1.0 dpm. Maximum Reactor power is 5%.

The Point Of Adding Heat should be approached slowly and cautiously. When the MSIVs are closed, heat removal capability of the Main Steam Line drains is limited.

4. ADJUST Control Rod position as necessary to establish a positive SUR AND RAISE reactor power to the POAH. ZLL

5. ADJUST control rods as necessary to achieve the following while continuing with this procedure:

• RCSTavgbetNeen547°Fand551°F

• Maintain Reactor Power 5%.

NOTE: It may be difficult to maintain the Reactor critical due to rapid changes in Xenon following a large power change. If the Reactor can NOT be stabilized due to operating limitations of the reactivity controlling systems, the Reactor shall be shutdown. Time spent with the Reactor critical and the secondary (turbine) secured should be minimized. If at any time the Reactor cannot be maintained stable and critical, then the Reactor shall be shutdown lAW GP-006-1.

(SOER 07-1, Recommendation #1)

6. IF 0% Power Activities are required lAW EST-105, THEN MAINTAIN Reactor Power AND COMMENCE EST-105 as recommended by the Reactor Engineer.

GP-005 Rev. 102 Page 27 of 107

Section 8.2 Page 3of8 INIT NOTE: The foNowing step may be performed when conditions permit while continuing with this procedure.

7. WHEN Reactor power is greater than 1%, THEN NOTIFY Reactor Engineering to COMMENCE logging data required by EST-067.

NOTE: ITS LCO 3.4.2 identifies RCS Minimum Temperature for Criticality as 530° F.

RCS temperature shall be monitored to ensure compliance with this LCO.

8. IF a Cold Shutdown preceded this startup AND OST-206 has NOT been performed within the previous 30 days, THEN: (SR 3.7.4.5)

/

a. PERFORM OST-206. A)JAr

b. UPDATE OST-920.

9. IF the Main Steam Isolation Valves are NOT open, THEN PERFORM the following:

a. VERIFY RCS temperature is being controlled lAW OP-405 section for Controlling RCS Temperature OR Controlling RCS Temperature With the MSIVs Closed.

NOTE: The MSIV Bypass Valves have been determined to be Containment Isolation valves. Anytime these valves are not closed, the Main Steam attachment of OP-923 shall be performed and a dedicated operator stationed.

Closing the breaker for the MSIV Bypass Valve(s) is controlled and documented by OMM-007, Equipment Inoperable Record.

CAUTION Restoring power to a Main Steam Isolation Valve (MSIV) Bypass Valve will require entry into ITS LCO 3.6.3, Condition C.

b. UNLOCK AND CLOSE the breakers for the MSIV Bypass ValvesonMCC-8:

ii

- MS-353A, MSIV V1-3A BYPASS (MCC-8 CMPT IC) itit,4 MS-353B, MSIV V1-3B BYPASS (MCC-8 CMPT 2C)

- MS-353C, MSIVV1-3C BYPASS (MCC-8 CMPT 3C)

GP-005 Rev. 102 Page28oflO7j

Section 8.2 Page 4 of 8 8.2.9 (Continued) . lNlT

c. RECORD the time of ITS LCO 3.6.3 entry. TIME ,A1/A- (4-

d. Locally UNLOCK the handwheel for each MSIV Bypass Valve:

- MS-353A, MSIV VI-3A BYPASS 46 I(k

- MS-353B, MSIVVI-3B BYPASS MS-353C, MSIVV1-3C BYPASS

e. WHEN the steam lines have been drained of condensate lAW Attachment 10.4, THEN CYCLE the MSIV Bypass Valves as necessary to warm up the Main Steam Lines AND EQUALIZE pressure across the MSIVs:

- MS-353A, MSIV Vl-3A BYPASS ,4J14 MS-353B, MSIVV1-3B BYPASS A1/4

- MS-353C, MSIVV1-3C BYPASS NOTE: When steam line pressure is within 50 psig of steam header pressure AND the MSIV switches are in the OPEN position, the MSIVs will open.

f. PLACE the MSIV switches in the OPEN position.

VI -3A, MSIV

- V1-3B, MSIV IJ1A

- V1-3C,MSIV

g. VERIFY the three MSIVs OPEN when header AND line pressure are within 50 psig of each other:

- V1-3A,MSIV ,4Jf4

- V1-3B,MSIV

- V1-3C,MSIV w64 GP-005 Rev. 102 Page 29 of 107

Section 8.2 Page 5 of 8 9 (Continued) INIT VERI

h. WHEN the MSIVs have opened, THEN PERFORM the following:

(1) CLOSE the MSIV Bypass Valves:

- MS-353A, MSIVVI-3ABYP Al, I(A 4

- MS-353B, MSIVVI-.3B BYP A(4 /\)/14

- MS-353C, MSIVVI-3C BYP J44 ,iM (2) LOCK OPEN the breakers for the MSIV Bypass Valves:

- MS-353Aon MCC-8 CMPT 1C 4 WA

- MS-353B on MCC-8 CMPT 2C

- MS-353C on MCC-8 CMPT 3C A114 ,i(A (3) LOCK the handwheels for the MSIV Bypass Valves:

- MS-353A M/A i(4

- MS-353B ij44 JAJ/A

- MS-353C Al/A 6 A1(A (4) RECORD the time of ITS LCO 3.6.3 exit. TIME /V(/j /J (5) DRAIN any moisture which may have collected in the MSIV Supply Filters using the filter drain valves.

F-55A Filter F-55B Filter AJ(A F-55C Filter GP-005 Rev. 102 Page 30 of 107j

I Section 8.2 Page 6of8 INIT

10. VERIFY Steam Dump controls are aligned as follows:

NOTE: A PC-464B, MS STEAM HDR PRESS AUTO/MAN STATION, potentiometer setting of 7.17 equates to a steam pressure of 1005 psig and a saturation temperature of approximately 547°F.

CAUTION Prior to rolling the Turbine, the Reactor should be maintained at less than 8% power and Tavg between 547°F and 551 °F.

- PC-464B, MS STEAM HDR PRESS AUTO/MAN STATION, potentiometer is set to maintain 547°F to 551 °F

- STEAM DUMP CONTROL switch to ON

- STEAM DUMP MODE switch to STEAM PRESS

- PC-464B, MS STEAM HDR PRESS AUTO/MAN STATION, is 47 in AUTO ADJUST PC-464B as necessa to maintain 547°F to 551 °F WHEN Steam Dump is controlling RCS temperature, THEN VERIFY the Controlling RCS Temperature section of OP-405 is completed.

}fj GP-005 I Rev. 102 I Page31of107

Section 8.2 Page 7 of 8 INIT

11. VERIFY the Gland Seal Steam and Drain System is aligned lAW OP-502, using Main Steam as the supply, while continuing with this procedure.

NOTE: P1-I 380A, HP TURBINE STEAM TO PCV-1 380 and Fl-i 381A, HP TURBINE STEAM TO PCV-1381 INDICATOR indicate the HP turbine outlet pressure. P1-138DB, HP TURBINE STEAM RETURN FROM PCV-1380 and P1-1381 B, HP TURBINE STEAM RETURN FROM PCV-1381 INDICATOR indicate pressure in the Cylinder heating gland. Gland pressure must be slightly above that of the HP outlet. Therefore, P1-i 38DB should read higher than Pl-1380A AND P1-1381B should read higher than PI-1381A. If water is present where the rotor exits the gland, it is an indication that cylinder heating is NOT adequate and that differential pressure should be raised.

Cylinder Heating Steam pressure may NOT be stable with Turbine loads less than 100% therefore, adjustments should be made only after consulting with RES. (OP-405, NCR 329164.)

CAUTION Transferring Gland Seal Steam supply from Auxiliary Steam to Main Steam may disrupt the balance between Cylinder Heating Steam and Gland Seal Steam. This may lead to elevated Turbine vibrations/eccentricity and/or hot water blowing out of the HP Turbine Glands. Step 8.2.12 is a continuous action step that shall be performed as Cylinder Heating Steam conditions indicate. (NCR 329164)

12. VERIFY Cylinder Heating Steam operation as follows:

a. Using PlC-I 380 and PlC-I 381, DETERMINE AND ADJUST the pressure difference between the cylinder heating gland and high pressure turbine outlet to IA approximately 5 psid.

b. IF required to maintain adequate sealing steam pressure, THEN THROTTLE MS-72, REAR CYLINDER HEATING REG BYPASS, as necessary.

c. IF required to maintain adequate sealing steam pressure, THEN THROTTLE MS-61, FRONT CYLINDER HEATING REG BYPASS, as necessary.

d. LOG any adjustments in Auto log.

GP-005 Rev. 102 Page 32 of 107

Section 8.2 Page 8 of 8 I IT

13. PERFORM Attachment 10.3, Venting the Feedwater Heaters, while continuing with this procedure.

14. CYCLE SIG Feedwater Regulating Valves, as follows:

a. VERIFY CLOSED the Feedwater Header Section Valves:

V2-6A, FW HDR SECTION V2-6B, FW HDR SECTION

- V2-6C, FW HDR SECTION

b. STATION an Operator to observe FRV cycling.

c. STROKE the Feedwater Regulating Valves to full open, then to full closed.

FCV-478 FCV-488 FCV-498

15. DRAIN the steam headers using Attachment 10.4, Draining the Steam Headers.

NOTE: The accumulation of sediment and air in the sensing lines may cause the feed flow and steam flow transmitters to indicate improperly. PM-166 may need to be performed any time the BOP is cooled down and depressurized to ensure the transmitters are properly vented.

16. IF the accuracy of the feed flow AND steam flow indicators is suspect, THEN BLOWDOWN the Steam Flow AND Feed Flow transmitters lAW PM-166. tJ4j I&C

17. WHEN Steam is supplied to the secondary, THEN VERIFY the HDT Level Controller (LC-1 530) is operating properly.

GP-005 Rev. 102 Page 33 of 107

Section 8.3 Page 1 of 22 INIT 8.3. Rolling the Turbine NOTE: During power ascension, all indications of reactor power level should be monitored and compared at 10% intervals. Indications such as core T and Turbine First-Stage Pressure should be compared to NI indications and Continuous Calorimetric Program percent power. If all indications do not agree within 5% of each other, then Reactor Power should be stabilized, OST-OlO performed, and plant management contacted for further instructions.

(SOER 90-003, Recommendation la)

1. PLACE the EH Fluid System in service lAW OP-503, E. H. Fluid System, the section entitled, Placing the E.H. Fluid System in Service for Turbine Operation.

NOTE: The following step may be performed at any time during this procedure.

2. IF NOT performed during the previous month, THEN PERFORM OST-554, Turbine Bearing Oil System and E-H Control System Hydraulic Components Test (Monthly).

Date last performed CAUTION Prior to rolling the Turbine, the Reactor should be maintained at less than 8% power and Tavg between 547°F and 551 °F.

The AT-POWER Reactor Trips are automatically unblocked as Reactor power or Turbine load is raised above 10% (permissive circuit P 7). Conversely, these trips are automatically blocked as Reactor power and Turbine load are lowered below the P-7 setpoint. The AT-POWER Reactor Trips are:

- Pressurizer High Level

- Pressurizer Low Pressure

- Reactor Coolant Low Flow

- Reactor Coolant Pump Bus Undervoltage and Underfrequency

- Reactor Coolant Pumps tripped

3. STATION a dedicated Feedwater Operator to control SIG levels between 40% and 50% until the Feedwater Regulating Valves areA)

GP-005 Rev. 102 Page 34 of 107

Section 8.3 Page 2 of 22 INIT VERI

4. WHEN the normal Feedwater Flow has been established AND the MDAFW Pumps are no longer being used to feed the S/Gs, THEN PERFORM the following to prevent back-leakage from the S/Gs.

a. OPEN V2-16A, AFW HDR DISCH.

b. CLOSE V2-16A, AFW HDR DISCH.

c. OPEN V2-16B, AFW HDR DISCH.

d. CLOSE V2-16B, AFW HDR DISCH.

e. OPEN V2-16C, AFW HDR DISCH.

f. CLOSE V2-16C, AFW HDR DISCH.

NOTE: During turbine roll and trip testing activities several transitions between Mode 1 and Mode 2 may occur. Completion of a Mode Checklist for each transition is not required provided the conditions established for Mode 2 and Mode I entry have been maintained.

5. WHEN Reactor Power approaches 5%, THEN PERFORM the following:

a. MAKE a plant announcement that MODE I has been entered. (1

b. CHANGE ERFIS Mode Indication to display MODE I

6. ADJUST Control Rods to maintain Reactor Power between 5°/

and 8% while continuing with this procedure.

GP-005 Rev. 102 Page 35 of 107

Section 8.3 Page 3of22 INIT NOTE: Steps 8.3.7 through 8.3.10 may be performed concurrently.

7. VERIFY cooling water is being supplied to the following components lAW OP-903, Placing Secondary Coolers in Service:

a. Generator Hydrogen Coolers

b. 2 Seal Oil Coolers H

c. Turbine Lube Oil Coolers

d. Exciter Air Coolers NOTE: The Turbine Generator recorders and instruments are normally stopped and started via the clearance process for work on the Turbine and/or Generator.

The Generator Temperature Recorder may have been shutdown independent of the clearance process due to nuisance (false) alarms on APP-009-E3, GEN STATOR HI DELTA TEMP.

Re-start of the Generator Temperature Recorder may cause APP-009-E3 to go into alarm while the internal math processer re-starts and the various circuits perform their self-test.

8. IF the Generator Temperature Recorder is shutdown, THEN re-start the recorder as follows:

a. OPEN the small, drop-down, keypad cover to expose the numeric keypad and control buttons.

b. PRESS the START button to re-start the recorder.

c. CHECK that the recorder performs its automatic re-start self-tests.

d. VERIFY the recorder is displaying the desired indications.

e. IF an OPS-NGGC-1 308 Status Control Tag was placed on the recorder at the time of recorder shutdown, THEN remove the tag lAW OPS-NGGC-1308.

GP-005 Rev. 102 I Page 36of 107

Section 8.3 Page 4 of 22 INIT

9. VERIFY the following recorders AND associated instruments monitoring the Turbine Generator are energized AND functional to the point necessary to support Turbine operation:

a. Turbine Generator Supervisory Recorder

b. Turbine MSR Temperature Recorder

c. Turbine Supervisory Alarm Mimic Display

d. Generator Temperature Recorder NOTE: APP-008-A8, Turbine Supervisory Instrument, will alarm when the Turbine Supervisory Instrumentation (TSI) is sensing an eccentricity >3 mils (0.003 inches).

AOP-006, Turbine EccentricityNibration, is applicable after the Turbine is latched. The Turbine is latched in Step 8.3.14.

10. IF Turbine rotor eccentricity is greater than or equal to 0.003 inches (3.0 mils) as indicated on the Turbine Generator Supervisory Recorder, ECCENTRICITY (HP ROTOR), OR in alarm on the RTGB Mimic Display, THEN PERFORM the following:

a. NOTIFY Engineering to evaluate acceptance of rolling the turbine.

b. REQUEST Engineering provide recommended actions PRIOR to exceeding 600 RPM.

c. IF Engineering determines that actual rotor eccentricity is NOT acceptable to roll the turbine, THEN PERFORM the following:

(

(1) NOTIFYtheSM (2) RESOLVE prior to continuing with this procedure. f\J/ik (3) DOCUMENT the problems encountered via a Nuclear Condition Report (NCR).

NCR#

GP-005 Rev. 102 Page 37 of 107 w

Section 8.3 Page 5 of 22 INIT NOTE: Turbine warmup times as required by Curve 7.8 of the Station Curve Book shall be observed. The minimum time to accelerate to sync hronous speed should be greater than 10 minutes. Data from Curve 7.8 is provided in Attachment 10.6, Turbine Recommended Start-Up and Loading Times.

CAUTION Turbine speed shall NOT be held in a resonant speed range as indicated on Curve 7.10 of the Station Curve Book.

There may be a small rise in Steam Flow as the Turbine is latched. This is acceptable since the Steam Dump system will automatically make adjustments to maintain Steam Pressure and, thus, Tavg and Reactor Power. The analys is in EC 63785 assumes that Reactor Power will stay less than 10% while making prepar ations to latch the Turbine and using Steam Dumps to control Reactor Power and Tempe rature with an allowance for operation up to 15% for short periods. Maximum allowed Reactor Power prior to latching the Turbine is 8% power.

11. Using Curve 7.8 or Attachment 10.6, DETERMINE the Time Required to Accelerate to Sync Speed based on TURBINE MSR TEMPERATURE RECORDER point #3, IMPULSE CHAM BER METAL indicated initial temperature.

Temperature: °F Time: f2 minuL

12. DEPRESS the VALVE POSITION LIMIT v (lower) pushbutton until the VALVE POSITION LIMIT indicator registers 0% Valve Limit Position.

GP-005 Rev. 102 Page 38 of 107

Section 8.3 Page 6 of 22 INIT NOTE: Engineering personnel will monitor the turbine startup follow ing replacement or repair of any Turbine Shaft components or bearings and will coordinate closely with the Control Room to ensure turbine limitations are not exceeded. Step 8.3.13 is a Continuous Action Step and is applicable from the start of turbine latch activities until the turbine is stable at 1800 RPM with acceptable vibration indications.

Indications of excessive Turbine Governor Valve leaka ge include, but are not limited to, inability to raise RCS temperature with all Steam Dumps closed OR Turbine speed rising to a speed >100 RPM. (NCR 36492 9)

13. IF during the turbine startup it is required to stop the turbine to perform balancing activities, OR IF Turbine Governor Valve leakage is excessive, THEN PERFORM the following:

a. VERIFY Reactor Trip Block P-S Permissive illuminated.

b. MANUALLY TRIP the turbine by simultaneously depressing the THINK AND the TURBINE TRIP pushbuttons.

Al

c. GO TO AOP-007, Turbine Trip Below P-8, concurrently while continuing with Step 8.3.13.d if required.

d. IF Turbine Stop Valve leakage requires closing the MSIVs THEN PERFORM the following:

NOTE: Refer to Precaution and Limitation 5.0.40 concerning Auxili ary Boiler capacity while continuing with this step.

(1) VERIFY sufficient Auxiliary Boilers are operating lAW OP-401 to provide Auxiliary Steam for Gland Seal.

(2) ALIGN Gland Seal with Auxiliary Steam as the supply lAW OP-502 section for Placing the Gland Seal Steam and Drain System in Service Using Auxiliary Steam.

GP-005 Rev. 102 Page 39 of 107

Section 8.3 Page 7 of 22 8.3.13.d (Continued) INIT NOTE: It may be difficult to maintain the Reactor critical due to rapid changes in Xenon following a large power change. If the Reactor can NOT be stabilized due to operating limitations of the reactivity controlling systems, the Reactor shall be shutdown. Time spent with the Reactor critical and the secondary (turbine) secured should be minimized. If at any time the Reactor can NOT be maintained stable and critical, then the Reactor shall be shutdown lAW GP-006-1. (SOER 07-1, Recommendation #1)

Operation of Main Steam PORVs OR the above and below seat drains for temperature control will require the use of a dedicated operator and the implementation of OP-923.

(3) MAINTAIN Reactor Power at approximately 1% to 3%. /J(A (4) TRANSFER RCS temperature control to the Above and Below Seat Drains lAW OP-405 section for Controlling RCS Temperature. )J(I;4 (5) ADJUST Steam Generator Blow Down flow as required to assist in RCS temperature control. i(A (6) IF required, THEN PERFORM OP-405 section for Controlling RCS Temperature With the MSIVs Closed to assist in RCS temperature control.

(7) CLOSE MSIVV1-3A, V1-3B, and V1-3C.

(8) WHEN Turbine repairs are complete AND it is desired to open the MSIVs, THEN PERFORM an additional Section 8.2 AND ATTACH it to this procedure.

(9) N!A the remainder of Section 8.3.

e. WHEN turbine balancing activities are complete, AND it is desired to roll the turbine, THEN PERFORM an additional Section 8.3 AND ATTACH it to this procedure. AJ(A

f. NIA the remainder of Section 8.3. /JJ4 GP-005 Rev. 102 Page 40 of 107

Section 8.3 Page 8 of 22 INIT NOTE: An Operator should be stationed at the Turbine prior to latching and during Turbine startup to detect rubbing or other abnormal noises when the Turbin e is rolled and to perform the local turbine operations as directed by the Contro l

Room.

The OVERSPEED PROTECT CONTROL light on the Turbine EH Displa y

Panel may be illuminated when operating at low power conditions (<10%) and may result in intermittent alarms on APP-009-E2, GOV CAB MONITOR TROUBLE. This will clear after the unit is synchronized to the grid and power is

> 10%. However, if the alarm is received, the APP should be referenced to ensure other possible causes of the alarm do not exist.

The SPEED CHAN light on the Turbine EH Display Panel may flash at turbine speeds less than 600 rpm and may result in intermittent alarms on APP-009-E2, GOV CAB MONITOR TROUBLE.

The guidance and direction found in AOP-006, Turbine EccentricityNibratio n, is applicable once the Turbine is latched.

14. DEPRESS AND HOLD the Turbine LATCH pushbutton until local indication Pl-63AS0, AUTO STOP OIL PRESS, is >80 psig. /

15. WHEN Pl-63ASO, AUTO STOP OIL PRESS, is >80 psig, THEN VERIFY the following:

SL, and SR, Turbine Stop Valves, indicate OPEN on the EH TURBINE CONTROL panel.

I RL, 2RL, 1 RR, 2RR, Reheat Stop Valves, indicate OPEN the EH TURBINE CONTROL panel.

IlL, 21L, IIR, 21R, Intercept Valves, indicate OPEN on the TURBINE CONTROL panel.

GLU, GLL, GRU, GRL, Governor Valves, indicate CLOSED or the EH TURBINE CONTROL panel.

Green LATCH light is ILLUMINATED.

UNIT TRIP light is EXTINGUISHED.

GP-005 I Rev. 102 Page 41 of 1071

)

Section 8.3 Page 9 of 22 INIT NOTE: Higher than expected EH Pump discharge and/or drain flows indicate an EH Dump Valve may be failed open. This condition will prevent the opening of one or more Turbine Governor Valves.

16. RECORD the following data from the EH Pump (Governor Fluid Pump) local flow indications:

- E H OIL PUMP A DISCHARGE FLOW c9 FI-4428A L GFL.-f/

E H OIL PUMP A DRAIN FLOW Fl-4427A 2 GP1CJáL-E H OIL PUMP B DISCHARGE FLOW FI-4428B 2 il.

GP E H OIL PUMP B DRAIN FLOW /

FI-4427B i GP

17. IF either EH Pump Discharge Flow reads >6 GPM OR IF either EH Pump Drain Flow >4 GPM THEN CONTACT the responsible system engineer for assistance.

(Print name of person contacted)

GP-005 Rev. 102 Page 42 of 107

Section 8.3 Page 10 of 22 INIT CAUTION The maximum time the Turbine shaft can be stati onary with gland seal applied is 15 minutes.

18. IF the Turbine has rolled off the Turning Gear AND it is desired to place the Turbine back on the Turning Gear, THE N PERFORM the following: (ACR 94-00310)

a. TRIP the Turbine by simultaneously depressing the THINK AND TURBINE TRIP pushbuttons.

b. CHECK the following valves have CLOSED:

SL and SR, Turbine Stop Valves IRL, 2RL, 1RR, 2RR, Reheat Stop Valves IlL, 2IL, llR, 21R, Intercept Valves c.

DEPRESS AND HOLD the Turbine LATCH pushbutto 4I14 n

until local indication PI-63AS0, AUTO STOP OIL PRE SS, is >80 psig.

1\) (it

d. WHEN Pl-63AS0, AUTO STOP OIL PRESS, is >80 psig THEN VERIFY the following:

(1) SL and SR, Turbine Stop Valves, indicate OPEN on the EH TURBINE CONTROL panel (2) 1 RL, 2RL, 1 RR, 2RR, Reheat Stop Valves, indicate OPEN on the EH TURBINE CONTROL panel (3) 1 IL, 2IL, I IR, 2IR, Intercept Valves, indicate OPEN on the EH TURBINE CONTROL panel (4) GLU, GLL, GRU, GRL, Governor Valves, indicate CLOSED on the EH TURBINE CONTROL panel (5) Green LATCH light is ILLUMINATED (6) UNIT TRIP light is EXTINGUISHED

e. VERIFY the Turbine back is on the Turning Gear.

GP-005 Rev. 102 I Page 43 of 107

Section 8.3 Page 11 of 22 8.3.18 (Continued)

INIT

f. IF the Turning Gear does NOT engage, THEN PER FORM the following:

(1) IF PI-2096A, TURBINE BEARING OIL PRESSURE INDICATOR, is > 6 psi 9 AND the Bearing Oil Lift Pump is operating, THEN PERFORM the following (a) PLACE the TURNING GEAR in OFF.

J/A (b) Locally PLACE the TURNING GEAR ENG/DISENG lever in the ENGAGED position.

(c) PLACE the TURNING GEAR in MANUAL.

(2) IF the Turning Gear AND Bearing Oil Lift Pumps are NOT operating, THEN CONTACT Engineering.

NOTE: The Turbine Valve/Trip Test shall be performed prior to startup lAW TRM TR4.4.1.

19. PERFORM the Turbine Valve/Trip Test:

a. TRIP the Turbine by simultaneously depressing the THINK AND TURBINE TRIP pushbuttons.

b. CHECK the following valves have CLOSED:

(1) SL and SR, Turbine Stop Valves (2) 1 RL, 2RL, I RR, 2RR, Reheat Stop Valves (3) ilL, 21L, 1IR, 2IR, Intercept Valves

c. DEPRESS AND HOLD the Turbine LATCH pushbutto n

until local indication PI-63AS0, AUTO STOP OIL PRE SS, is >80 p51g.

J GP-005 Rev. 102 Page 44 of 107

Section 8.3 Page 12 of 22 8.3.19 (Continued)

INIT

d. WHEN PI-.63AS0, AUTO STOP OIL PRESS, is >80 psig, THEN VERIFY the following:

(1) SL and SR, Turbine Stop Valves, indicate OPE N on the EH TURBINE CONTROL panel (2) 1 RL, 2RL, I RR, 2RR, Reheat Stop Valves, indic ate OPEN on the EH TURBINE CONTROL pane l

(3) ilL, 21L, 1IR, 21R, Intercept Valves, indicate OPE N

on the EH TURBINE CONTROL panel (4) GLU, GLL, GRU, GRL, Governor Valves, indic ate CLOSED on the EH TURBINE CONTROL pane l

(5) Green LATCH light is ILLUMINATED (6) UNIT TRIP light is EXTINGUISHED

e. DIRECT an Operator to trip the Turbine LOC ALLY at the Turbine Front Standard by positioning the Turb ine Trip Lever to the TRIP position.

f. CHECK the following valves have CLOSED.

SL and SR, Turbine Stop Valves I RL, 2RL, 1 RR, 2RR, Reheat Stop Valves ilL, 21L, 1IR, 21R, Intercept Valves

g. DIRECT the Operator at the Turbine Front Stan dard to reset the Turbine LOCALLY by placing the Turb ine Trip Lever to RESET and HOLDING (lever will be relea sed in Step 8.3.19.i).

j GP-005 I Rev. 102 I Page 45 of 107

Section 8.3 Page 13 of 22 8.3.19 (Continued)

INIT

h. CHECK the following:

SL and SR, Turbine Stop Valves, indicate OPEN on the EH TURBINE CONTROL panel 1 RL, 2RL, 1 RR, 2RR, Reheat Stop Valves, indicate OPEN on the EH TURBINE CONTROL panel I IL, 21L, 1 IR, 2IR, Intercept Valves, indicate OPEN on the EH TURBINE CONTROL panel GLU, GLL, GRU, GRL, Governor Valves, indicate CLOSE.

on the EH TURBINE CONTROL panel )

Green LATCH light is ILLUMINATED /

UNIT TRIP light is EXTINGUISHED

i. WHEN PI-63ASO, AUTO STOP OIL, indicates greater than 80 psig, THEN POSITION the Turbine Trip Lever to NORMAL.

NOTE: Step 8.3.21 is NOT required as long as PIC-838, TURBINE VALV E LIMIT SWITCH ADJUSTMENT, AND MST-551, TURBINE TRIP LOGIC CHAN NEL TESTING, were satisfactorily completed during the Refueling Outage and as approved by the System Engineer.

20. RECORD date PIC-838 AND MST-551 completed.

Date PIC-838 7/f9/iL Date MST-55 I 7//j < A-4

21. IF required, THEN TEST the OVERSPEED PROTECTION CONTROLLER as follows:

a. TURN the OVERSPEED PROTECTION CONTROLLER switch to TEST, AND CHECK all Intercept Valves close rapidly.

1ILCLOSED

- hR CLOSED 21L CLOSED

- 21R CLOSED GP-005 Rev. 102 Page 46 of 1O7

Section 8.3 Page 14 of 22 8.3.21 (Continued)

INIT

b. TURN the OVERSPEED PROTECTION CONTROLLER switch to IN SERVICE, AND CHECK all Intercept Valves reopen.

1ILOPEN hR OPEN 2lL OPEN 21R OPEN

22. DEPRESS the VALVE POSITION LIMIT A (raise) pushbutton unti7/

the VALVE POSITION LIMIT indicator stops rising.

23. DEPRESS the OPER AUTO pushbutton.

CAUTION If the AVP cards are NOT in Automatic, they should NOT be restored to Autom atic while the Turbine is latched. Restoration while latched could result in governor valve swings and Reactor Power swings.

24. At the E-H Cabinet, CHECK the AVP cards are in Automatic.

(Refer to Attachment 10.7, EH AVP CARDS) (NCR 433833)

25. SET a speed of 520-570 rpm in the SETTER display using the REF V and/or REF A pushbuttons.

26. SET the ACCELERATION RATE thumbwheel to 50 rpm/minute.

GP-005 Rev. 102 Page 47 of 107 4

Section 8.3 Page 15 of 22 INIT NOTE: When the REFERENCE display has reached the indicated SETTE R value, the GO lamp will extinguish and the rotor speed will approximately equal the indicated REFERENCE speed.

Governor Valve leakage may cause Turbine speed to rise above the value placed into the SETTER. Transferring Turbine E-H Controls to MANUAL has proven to be successful in controlling this situation. (NCR 32922 3)

CAUTION The Turbine will roll off the Turning Gear as speed rises. Turbin e speed shall be monitored closely and take actions necessary to avoid prolon ged operation in resonant speed ranges as shown on Curve 7.10.

Turbine speed shall NOT be allowed to exceed 1000 rpm unless speed is positively controlled by the Operator and the El-IC System.

Reactor Power should be maintained <15% power prior to synchr onizing the Generator to the grid.

The AT-POWER Reactor Trips are automatically unblocked as Reactor power or Turbine load is raised above 10% (permissive circuit P 7). Conversely, these trips are automatically blocked as Reactor power and Turbine load are lowere d below the P-7 setpoint.

The AT-POWER Reactor Trips are:

- Pressurizer High Level

- Pressurizer Low Pressure

- Reactor Coolant Low Flow

- Reactor Coolant Pump Bus Undervoltage and Underfrequency

- Reactor Coolant Pumps tripped

27. WHEN steam inlet pressure is at least 600 psig as indicated on P1-i 304, HP TURB THROTTLE PRESS, AND Condenser back pressure is less than or equal to 5 inches Hg Abs on P1-1310, LP TURB A COND PRESS INDICATOR, and P1-1311, LPTURB B COND PRESS INDICATOR, THEN DEPRESS the GO pushbutton to raise speed.

/

GP-005 Rev. 102 Page 48 of 107

Section 8.3 Page 16of22 INIT

28. PERFORM the following as Turbine speed rises:

a. VERIFY Turning Gear disengages.

b. IF Governor Valve leakage is causing Turbine speed to raise above the speed set into the SETTER, THEN place the Turbine E-H Control into MANUAL (depress the TURB MANUAL button) in attempt to match the Reference Counter to actual Turbine speed. (NCR 329223)

c. IF Turbine speed stabilizes in a resonant speed range, THEN RAISE speed as necessary to stabilize in a non-resonant speed range lAW Curve 7.10.

4/k

d. IF Turbine speed exceeds 1000 rpm AND is NOT under positive control of the Operator, THEN GO TO Step 8.3.13.

29. WHEN Turbine speed stabilizes, THEN PERFORM the following steps concurrently:

a. CHECK the following Turbine Supervisory instruments for normal turbine operation:

Turbine Generator Supervisory Recorder Turbine MSR Temperature Recorder Turbine Supervisory Alarm Mimic Display Generator Temperature Recorder GP-005 Rev. 102 Page 49 of 107

Section 8.3 Page 17of22 8.3.29 (Continued)

INJI CAUTION OP-506 contains the limits for Turbine Bearing temperatures. APP-008-E1, LUBE TEMP, contains directions if there are con OIL HI cerns about Turbine Bearing Temperatures. A manual Turbine Trip is recommended if any Turbine Bearing Metal temperatures exc 225°F. eed Exhaust hood temperature should not be allowed to exceed 175°F with exhaust hood out of service. If the temperature cannot spray be reduced to less than 175°F, the unit should shutdown and the trouble corrected. The be maximum exhaust hood temperature permitted 250° F for a maximum of 15 minutes. is A manual Turbine trip is required if any Exhaus indication shows a valid temperature of t Hood 250°F or greater for greater than 15 minutes.

(EC 69831, EC 74557, APP-008)

b. DIRECT an Operator to locally check the follo wing:

Proper lube oil flow in each bearing sightg lass Bearing oil return temperatures lAW OP-506 Attachment 10.2 Exhaust Hood temperatures at the South side of the Turbine 1

Rubs and other unusual noises

c. IF Turbine Rotor Supervisory Alarms are rece ived as indicated locally OR on the Turbine Gen erator Supervisory Recorder OR in alarm on the RTGB Mimic Display, THEN NOTIFY Engineering prior to raising turb ine speed. /

30. WHEN the Turbine Supervisory Instrument checks and local Turbine checks are completed AND conditi ons are satisfactory for Turbine acceleration, THEN PERFORM the following:

a. IF Turbine E-H Controls were placed into TURB MANUAL to control the Turbine Speed, THEN return the E-H Controls to AUTO by depressing the OP ER AUTO button.

b. IF E-H Controls were transferred from TURB MANUAL to OPER AUTO, THEN check that the Turbine Speed numbers in the REFERENCE and SETTER windows are in agreement.

GP-005 Rev. 102 Page 50 of 107

Section 8.3 Page 18 of 22 8.3.30 (Continued)

c. SET a speed of 950-1000 rpm in the SET TER display.

NOTE: With the Bearing Oil Lift Pump Control Switch in the AUTO position, the Bearing Oil Lift Pump should stop whe n Bearing Oil Pressure is above the setpoint for pressure switch 63TG. This occ urs at a turbine speed of approximately 600 RPM and rising. (Re ference CWD B-i 90628, Sheet 732)

The Turbine Supervisory Recorder will transfer from monitoring Turbine Eccentricity to Turbine Vibration when the Turbine speed is approximately 600 RPM and rising. This is controlled thro ugh the Turbine Supervisory Instrumentation (TSI) cabinets.

31. DEPRESS the GO pushbuUon to raise spe ed.

32. WHEN Turbine speed is >600 RPM and rising, THEN CHECK the following actions have automatically occ urred:

. The Bearing Oil Lift Pump is STOPPED.

. The Turbine Supervisory Recorder has TR ANSFERRED recording Turbine Eccentricity to Turbin e Vibration.

33. VERIFY the Turbine speed stabilizes at 950

-1000 rpm.

NOTE: An elevated acceleration rate is require d between 1000 AND 1300 rpm to minimize the time the turbine remains in the LP turbine resonant speed ranes.

34. SET the ACCELERATION RATE thumb wheel to 300 rpm/mm.

35. SET a speed of 1300-1400 rpm in the SET TER display.

36. DEPRESS the GO pushbutton to raise spe ed.

37. WHEN Turbine speed is 1300-1 400 rpm, THEN VERIFY the Turbine speed stabilizes at 1300-1400 rpm.

38. IF the time for heat soak recorded in Ste p 8.3.11 has NOT elapsed, THEN ALLOW turbine temperatur es to stabilize.

39. WHEN the time recorded in Step 8.3.11 has elapsed, THEN a speed of 1800 rpm in the SETTER display.

GP-005 Rev. 102 Page 51 of ij

Section 8.3 Page 19 of 22 INIT NOTE: Due to the HP turbine rotor critical speed and LP turbine resonant speed ranges, it is desired to accelerate at 100 rpm/minute through the 1400 rpm to 1700 rpm range.

40. SET the ACCELERATION RATE to 100 rpm/minute.

41. DEPRESS the GO pushbutton as necessary to raise speed.

42. VERIFY the Turbine speed stabilizes at 1800 rpm.

43. WHEN Steam is supplied to the secondary, THEN VERIFY the HDT Level Controller (LC-1 530) is operating properly.

44. IF Engineering requires a Turbine Valve/Trip Test from 1800 rpm, THEN PERFORM the following:

a. VERIFY the Turbine is at 1800 rpm.

b. TRIP the Turbine by simultaneously depressing the THINK AND TURBINE TRIP pushbuttons.

c. CHECK the following valves have CLOSED:

SL and SR, Turbine Stop Valves 1 RL, 2RL, I RR, 2RR, Reheat Stop Valves ilL, 21L, IIR, 21R, Intercept Valves

d. DEPRESS the VALVE POSITION LIMIT V (lower) pushbutton until the VALVE POSITION LIMIT indicator registers 0% Valve Limit Position.

e. DEPRESS AND HOLD the Turbine LATCH pushbutton UNTIL local indication Pl-63ASO, AUTO STOP OIL PRESS, is > 80 psig.

f GP-005 Rev. 102 Page 52 of 107

Section 8.3 Page 20 of 22 8.3.44 (Continued)

f. WHEN Pl-63AS0, AUTO STOP OIL PRESS, LN]I is > 80 psig, THEN VERIFY the following:

SL and SR, Turbine Stop Valves, indicate OPE N on the EH TURBINE CONTROL panel I RL, 2RL, I RR, 2RR, Reheat Stop Valves, indic ate OPEN on the EH TURBINE CONTROL panel IlL, 21L, IIR, 21R, Intercept Valves, indicate OPEN on_-4f the EH TURBINE CONTROL panel (rZ L GLU, GLL, GRU, GRL, Governor Valves, indic ate CLOSED on the EH TURBINE CONTROL pane l

Green LATCH light is ILLUMINATED UNIT TRIP light is EXTINGUISHED

g. DEPRESS the VALVE POSITION LIMIT (rais e) pushbutton until the VALVE POSITION LIM IT indicator stops rising.

h. DEPRESS OPER AUTO pushbutton.

IF Turbine speed is 1000 rpm, THEN PERFORM the following:

(1) SET a speed of 950 1000 rpm in the Setter display.

(2) IF required, THEN DEPRESS the GO pushbutto n to raise speed. i1 (3) WHEN Turbine speed is 950-1000 rpm, THE N

VERIFY the Turbine speed stabilizes at 950-1000 rpm.

GP-005 Rev. 102 Page 53 of 107

Section 8.3 Page 21 of22 8.3.44 (Continued)

ItflT NOTE: Higher acceleration rate is required between 1000 AND 1300 rpm to minim ize the time the turbine remains in the LP turbine resonant speed ranges

j. IF Turbine speed was 1400 rpm after trip testing, THEN PERFORM the following:

(1) SET the ACCELERATION RATE thumbwheel to 300 rpm/mm.

(2) SET a speed of 1300-1400 rpm in the SETTER display.

(3) DEPRESS the GO pushbutton as necessary to raise speed.

(4) WHEN Turbine speed is 1300-1400 rpm, THEN VERIFY the Turbine speed stabilizes at 1300-1400 rpm. (

NOTE: Due to the HP turbine rotor critical speed and LP turbine resonant speed ranges, it is desired to accelerate at 100 rpm/minute through the 1400 rpm to 1700 rpm range.

k. VERIFY the ACCELERATION RATE SET to 100 rpm/minute.

I. SET a speed of 1800 rpm in the SETTER display.

m. DEPRESS the GO pushbutton as necessary to raise GP-005 Rev. 102 Page 54 of 107

Section 8.3 Page 22 of 22 INIT CAUTION If the Generator can NOT be synchronized and loaded within 5 minutes after reaching 1800 RPM, then the Exhaust Hood Temperature should be monitored locally. The maximum exhaust hood temperature permitted is 250°F. A manual Turbine trip is required if any Exhaust Hood indication shows a valid temperature of 250°F or greater for 15 minutes. (EC 69831, APP-008)

45. At 1800 rpm, PERFORM the following:

a. RECORD the Main Oil Pump Discharge pressure from PI-63M0P on the Front Standard.

b. IF Main Oil Pump pressure is less than 350 psig, THEN CONTACT Engineering AND RESOLVE the discrepancy before continuing wiJhtArocedure.

Engineering Contaét (Print name)

c. STOP the TURNING GEAR AND SEAL OIL BACKUP PUMPS AND PLACE the control switch in the AUTO position.

d. STOP one of the two running GOV FLUID PUMPS AND PLACE the control switch in the AUTO position.

- GOV FLUID PUMP 4 LEFT RUNNING

- GOV FLUID PUMP STOPPED with switch in

e. VERIFY the BEARING OIL LIFT PUMP control switch is in the AUTO position.

46. IF scheduled, OR if required for for PMT, THEN PERFORM OST-551 -2.

GP-005 I Rev. 102 I Page55of107

d1 )

Section 8.4 Page 1 of 25 INIT 8.4. Electrical Startup and Loading of Generator

1. CONTACT the Load Dispatcher (LD) for the following:

(

References:

2.1.10, SOER 10-1, Recommendation #6, and 2.4.16, OPEX 388359)

NOTIFY the LD that Robinson Unit 2 will be synchronized to th/

CONFIRM that voltage support will be maintained above minimum required voltage to support a Loss Of Coolant Accident (maintain Voltage Schedule). (SOER 99-01, Add. I Rec. 2a Fleet Item 3) L_1

2. CLOSE the Exciter Field Breaker.

3. PLACE the Voltage Regulator in service as follows:

NOTE: The Exciter Field Breaker may trip if Generator voltage exceeds 22.0 KV.

a. Slowly ADJUST Generator voltage, as indicated on GEN

øA-øB VOLTS OR ERFIS point ELV2800A, to 22.0 KV using the Manual Field Current Adjuster.

b. IF the Regulator Balance Meter does NOT indicate 0, THEN NOTIFY engineering for further guidance prior to proceeding.

NOTE: Placing the VOLTAGE REGULATOR in the TEST position disables the voltage followers. The time spent with the Voltage Regulator in the TEST position should be minimized.

c. PLACE VOLTAGE REGULATOR in AUTO.

GP-005 Rev. 102 Page 56 of 107

Wk Section 8.4 Page 2 of 25 INIT

4. PLACE the MAIN GENERATOR Synchroscope key switch in the GEN NORTH position.

NOTE: If Generator voltage is less than Switchyard voltage then adjusting the VOLTAGE ADJUSTER in the raise direction will cause % DIFF VOLTS to lower. If Generator voltage is greater than Switchyard voltage then adjusting the VOLTAGE ADJUSTER in the raise direction will cause % DIFF VOLTS to rise.

5. ADJUST the % DIFF VOLTS to zero using the VOLTAGE ADJUSTER.

6. ADJUST Turbine speed using the REF V and/or REF \ AND GO pushbuttons so that the Synchroscope is rotating SLOWLY in the FAST DIRECTION.

CAUTION The assumptions in EC 63785 allow Reactor Power above 10% for short periods of time as long as it is maintained <15%. Maintaining Reactor Power <10% prior to Generator synchronizing ensures a margin to this limit.

The AT-POWER Reactor Trips are automatically unblocked as Reactor power or Turbine load is raised above 10% (permissive circuit P-7). Conversely, these trips are automatically blocked as Reactor power and Turbine load are lowered below the P-7 setpoint. The AT-POWER Reactor Trips are:

- Pressurizer High Level

- Pressurizer Low Pressure

- Reactor Coolant Low Flow

- Reactor Coolant Pump Bus Undervoltage and Underfrequency

- Reactor Coolant Pumps tripped

7. VERIFY Tavg is at the high end of the 547°F to 551 °F band AND Reactor Power is 6% to 10%.

GP-005 Rev. 102 Page 57 of 107

Section 8.4 Page 3of25 INIT NOTE: The sequence of actions necessary to synchronize the unit to the grid is TIME CRITICAL. The RO, BOP, and Feedwater Operator shall verbally rehearse the actions of the following step and coordinate their actions at all times while synchronizing to the grid and loading the unit. It would be beneficial to have a dedicated stop watch operator to ensure contingency actions are not missed.

To reduce the magnitude of the transient when synchronizing to the grid, Tavg should be greater than 547°F and rising.

Experience has shown that a Control Rod withdrawal of 10 steps is optimum.

8. SYNCHRONIZE the Main Generator to the 230 Ky Grid as follows:

a. WITHDRAW Control Rods to raise Tavg.

b. WHEN the synchroscope is rotating SLOWLY in the FAST DIRECTION AND reaches a point equivalent to 5 minutes before the 12 oclock position, THEN CLOSE the NORTH COB BKR 52/9. Time CAUTION If GV#1 (GLU) and GV#3 (GLL) are not off their closed seats (Closed position lights EXTINGUISHED.) within 1 minute of closing the NORTH OCB BKR 52/9 when paralleling to the Grid, a Generator Lockout will occur. Turbine Control may be placed in TURB MAN and the GV A and GV V pushbuttons used as necessary IF OPER AUTO is not available or to pick up additional load.

IF it is necessary to re-open a Generator Output OCB, the THINK BUTTON must be held in the DEPRESSED position until the OCB indicates open.

c. IF GV#1 (GLU) OR GV#3 (GLL) remain CLOSED, THEN, within 30 seconds, ADJUST Turbine Load UP (NOT to exceed 70 MWe) until GV#1 (GLU) AND GV#3 (GLL) are off their closed seats (Closed position lights EXTINGUISHED.)

d. IF the turbine can NOT pick up at least 20 MWe, THEN SIMULTANEOUSLY DEPRESS AND HOLD the THINK BUTTON AND RE-OPEN the NORTH OCB BKR 52/9.

GP-005 Rev. 102 Page 58 of 107

Section 8.4 8.4.8 (Continued) Page 4 of 25

e. INIT IF the NORTH OCB BKR 52/9 was ope ned in the previous step, THEN INFORM the SM AND DO NOT continue with this procedure without management app roval.

f. IF the unit is at 70 MWe AND IF either GV#1 GV#3 (GLL) remains CLOSED, THEN with (GLU) OR in the next 30 seconds PERFORM the following:

- PLACE Turbine Control in TURB MANUAL AND USE the GV V pushbutton as necessary to she d load to minimum.

VERIFY Reactor Power is less than 10%

- SIMULTANEOUSLY DEPRESS AND HOL D the THINK BUTTON AND OPEN the NORTH OCB BKR 52/9.

g. IF the NORTH OCB BKR 52/9 was opened in step, THEN INFORM the SM AND DO NOT the previous CON11NUE with this procedure without managemen t approval.

9. PLACE the MAIN GENERATOR synchr oscope key switch in the GEN SOUTH position.

10. CLOSE the SOUTH OCB BKR 52/8.

Time

11. TURN the synchroscope key switch to the mid-position.

12. VERIFY CLOSED the Feedwater Regu lating Valves:

FCV-478 FCV-488 FCV-498 CAUTION PPP-007, Feedwater Leakage Test, allow s the rates up to 735 gpm each. Opening the Fee Feedwater Regulating Valves to leak by at dwater Header Section valves may cau over feed condition. se an

13. OPEN the Feedwater Header Section valv es:

V2-6A, FW HDR SECTION V2-6B, FW HDR SECTION

- V2-6C, FW HDR SECTION GP-005 Rev. 102 Page 59 of 107

Section 8.4 Page 5 of 25 INIT NOTE: Electrical load and Reactor power should be raised simu ltaneously to maintain the normal TavgTref program.

During power ascension, all indications of reactor pow er level should be monitored and compared at 10% intervals, Indications such as core T and Turbine First-Stage Pressure should be compared to NI indicat ions and Continuous Calorimetric Program percent power. If all indications do not agree within 5% of each other, then Reactor Power should be stabiliz ed, OST-OlO performed, and plant management contacted for further instructions.

(SOER 90-003, Recommendation 1 a) [CAPR ACR 93-284

]

14. STABILIZE the Unit at 10% to 15% Reactor Power.

NOTE: The following AT-POWER reactor trips are automatically unblocked when the REACTOR TRIP BLOCK P-7 permissive status light is exting uished:

Pressurizer High Level, Pressurizer Low Pressure, Reac tor Coolant Low Flow, Reactor Coolant Pump Bus Undervoltage and Underfre quency and Reactor Coolant Pumps Tripped.

If the unit is stabilized at greater than 10% Reactor Power, then Steps 8.4.15 through 8.4.26 may be performed when the specific condit ions for each step are met while the heat soak is in progress. Intent is to allow performance of steps that DO NOT raise Turbine load while completing the heat soak.

15. WHEN two Power Range detectors indicate greater than 10%,

THEN PERFORM the following:

a. CHECK POWER ABOVE P-iD permissive light ILLUMINATES. (ITS SR 3.3.1.8, Table 3.3.1-1 Items 2.b and 3)

b. CHECK REACTOR TRIP BLOCK P-7 permissive statu s

light is EXTINGUISHED. (ITS SR 3.3.1.1, Table 3.3.1-1 Item 17.e)

c. VERIFY one decade overlap exists between the Power Range AND Intermediate Range.

GP-005 Rev. 102 Page 60 of 107

Section 8.4 Page 6 of 25 8.4.15 (Continued)

INIT

d. BLOCK the Intermediate Range High Power Trip as follows:

(1) DEPRESS the INTERMEDIATE RANGE LOGIC TRIP DEFEAT TRAIN A pushbutton.

(2) DEPRESS the INTERMEDIATE RANGE LOGIC TRIP DEFEAT TRAIN B pushbutton.

(3) CHECK the INTERM RANGE TRIP BLOCKED permissive light is ILLUMINATED.

e. BLOCK the Power Range Reactor Trip Low Setpoint as follows:

(1) DEPRESS the POWER RANGE LOGIC TRIP DEFEAT TRAIN A pushbutton.

(2) DEPRESS the POWER RANGE LOGIC TRIP DEFEAT TRAIN B pushbutton.

(3) CHECK the LO POWER RANGE TRIP BLOCKED permissive light is ILLUMINATED.

NOTE: Balance of Plant operations are typically related to specifi c turbine loads. Due to the unavailability of % Turbine Load indications, BOP operations are related to Reactor Power and assumes that Tavg is mainta ined lAW the normal TavgTref program.

The Moisture Separator Reheater Purge Valves will remain open as long as Reactor Power remains above 10%.

f. WHEN greater than 10% power, THEN PERFORM the following:

(1) VERIFY the toggle switch inside the MSR TIMER VALVE CONTROLLER is in the ON position.

GP-005 Rev. 102 Page 61 of 107

Section 8.4 Page 7 of 25 8.4.1 5.f (Continued) INIT (2) POSITION the Moisture Separator PURGE VALVES switch to OPEN AND HOLD until the following valves open, as indicated on the RTGB:

VALVES IMT FCV-1 334A, MSR 1A TUBESIDE VENT TO CONDENSER FCV-1 334B, MSR 1 B TUBESIDE VENT TO CONDENSER FCV-1334C, MSR 2ATUBESIDE VENT TO CONDENSER FCV-1334D, MSR 2B TUBESIDE VENT TO CONDENSER V1-6-IA, MSR STEAM PURGE VALVE V1-6-2A, MSR STEAM PURGE VALVE V1-6-1B, MSR STEAM PURGE VALVE V1-6-2B, MSR STEAM PURGE VALVE

16. CHECK the following:

- SPEED CONTROL light is EXTINGUISHED.

- LOAD CONTROL light is ILLUMINATED.

17. IF Turbine E-H Controls were placed in TURB MAN to pick up additional load AND OPER AUTO is available, THEN return Turbine E-H Controls to AUTO by depressing the OPER AUTO button.

18. VERIFY the LPMS switch on the RTGB is in the NORM position AND REGARD all further alarms.

19. Prior to exceeding 15% power, VERIFY AFD within limits for each operable excore NI channel. (ITS SR 3.2.3.1)

a. IF AFD is NOT within limits, THEN CONTACT Reactor Engineering for technical guidance prior to exceeding 15%

power.

GP-005 Rev. 102 Page 62 of 107

Section 8.4 Page 8 of 25 INIT NOTE: APP-005-D6, ti Flux Warning / Status, should alarm within approximately one minute of average Power Range Power on ERFIS reading >15% Power ERFIS will give a printout of the current conditions.

FMP-009, Power Distribution Control, contains the necessary logs and compensatory actions IF the ERFIS Continuous Axial Offset Calculation program is not working.

CAUTION ITS SR 3.2.3.2 requires manual monitoring of Axial Flux Difference (AFD) within one hour of determining that the ERFIS Continuous Axial Offset Calculation progra m is working correctly. This is an hourly log requirement while Reactor Power <90% not is power.

When Reactor Power is 90% AND ERRS Continuous Axial Offset Calcul ation is OOS, this becomes a 15 minute log requirement. (

Reference:

FMP-009, Manua l Monitoring of AFD)

20. WHEN Reactor Power is greater than 15%, THEN PERFORM the following:

a. CHECK that APP-005-D6 is received.

b. IF APP-005-D6 is NOT received within 5 minutes of exceeding 15% power, THEN PERFORM the following:

(1) INFORM the Reactor Engineer that ERFIS Continuous Axial Offset Calculation is not working correctly.

(Print name of contact)

(2) INFORM the on-call ERFIS Computer Support (Nuclear Information Technology) person that ERFIS Continuous Axial Offset Calculation is not working correctly.

(Print name of contact)

(3) COMMENCE the required compensatory actions of FMP-009 section for ERFIS Out Of Service.

GP-005 Rev. 102 Page 63 of 107

Section 8.4 Page 9of25 8.4.20.b (Continued)

!t4J1 (4) LOG the following items:

(a) Time problem identified:

(b) Time of first FMP-009 Log entry.

(C) NCR number for ERFIS Continuous Axial Offset Calculation.

NOTE: ITS SR 3.3.1.2 requires a calorimetric be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of exceeding 15% Reactor Power.

c. PERFORM OST-OlO, Power Range Calorimetric during Power Operation Daily, within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

Time power exceeds 15%

Time OST-OlO complete

d. IF OST-OlO can NOT be performed immediately, THEN INITIATE a Required Event Tracking EIR lAW OMM-007.

e. PERFORM Attachment 10.5, Feedwater Heater Alignment.

GP-005 Rev. 102 Page 64 of 107

Section 8.4 Page 100f25 INIT NOTE: Step 8.4.2 1 is a continuous action step that should be perform ed whenever plant conditions require Feedwater flow through the FRVs and conditions are suitable for automatic SIG water level control.

Feedwater Regulating Valves should be transferred to automa tic control one at a time.

FCV-1446, CONDENSATE RECIRC, is controlled by FS-144 6, COND PMP RECIRC VLV FLOW SWITCH. FS-1446 is set to open FCV-1 446 at a flow of 1050 gpm with the valve closing at a Condensate System flow of 4200 gpm flow through the GS Condenser and SGBD Heat Exchan gers. (ESR 00-00208)

The Push Button to reset FS-1446 is located in the same enclosure as FS-1446. This enclosure is located approximately 15 feet northwest of FCV-1446 on a concrete column.

21. WHEN Reactor Power is 15% to 20%, OR the Feedwater Regulating Bypass Valves are at 60% to 90% demand signal, THEN SHIFT each Feedwater Regulating Valve to AUTO as follows:

a. CHECK CLOSED FCV-1446, CONDENSER RECIRC.

b. IF FCV-1446 does not indicate shut, THEN PERFORM the following:

(1) DEPRESS AND HOLD the FS-1446 Push Button.

(2) WHEN FCV-1 446 indicates full shut, THEN release the FS-1446 Push Button.

CAUTION Shutting either C-18A, FCV-1446 INLET, or C-18B, FCV-1446 OUTLET, could cause a running Condensate Pump to overheat on a low flow condition IF unit load is reduced prior to correcting the problem with FCV-1446.

(3) IF FCV-1446 is failed open OR reopens when it should stay closed, THEN SHUT either

- C-18A OR

- C-18B GP-005 Rev. 102 Page 65 of 107

Section 8.4 8.4.21.b (Continued) Page 11 of 25 (4) IF EITHER C-i 8A OR C-i 8B JNJI were shut in Step 8.4.21 .b(3), THEN HANG either an OFF NORMAL TAG lAW OPS-NGG C-1 308 OR a CAUTION TAG lAW OMM-001

-9 while continuing with this procedure.

TA G

NU MB ER

c. VERIFY Feed Flow is trending with Steam Flow AND S/G Levels are within 1% of progra m level.

S/GA S/G B S/GC

d. DEPRESS the AUTO pushbu tton on the FRV controller.

FCV-478 FEED REG VALVE A

FCV-488 FEED REG VALVE B

FCV-498, FEED REG VALVE C

IF the respective Feedwater Regulating Bypass Valve is NOT closed, THEN slowly clo se it.

FCV-479, FEED REG BYPA SS A FCV-489, FEED REG BYPASS B

FCV-499, FEED REG BYPASS

e. VERIFY each FRV in AUTO C is maintaining programmed S/G level.

FCV-478 FEED REG VALVE A

FCV-488, FEED REG VALVE B

FCV-498, FEED REG VALVE C

GP-005 Rev. 102 Page66ofi07

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01000105805 Task

Title:

Respond to RHR Leakage With the JPM No.: 2011-2 NRC JPM E Unit on RHR Cooling K/A

Reference:

025 AA2.02 3.4 / 3.8 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

• The plant is in Mode 5.

• RHR is in service for core cooling.

• Charging Pump A is cleared and tagged.

Task Standard: Isolate RHR system to stop leakage to the PRT Required Materials: AOP-020, Loss of Residual Heat Removal, Revision 32 OP-201, Residual Heat Removal System, Revision 64 General

References:

AOP-020, Loss of Residual Heat Removal, Revision 32 OP-201, Residual Heat Removal System, Revision 64 Handouts: OP-201, Section 8.2.3 with Steps 8.2.3.1 a and lb completed Initiating Cue: You are the RO. The CRS has directed you to swap to RHR Pump A in service lAW OP-201, Section 8.2.3 to equalize run time on the pumps.

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Time Critical Task: NO Validation Time: 10 minutes SIMULATOR SETUP

1. ResettolC-810

2. A Charging Pump inoperable 2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 13 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with a check mark)

START TIME:

Performance Step: I PLACE FC-605, RHR HX BYPASS FLOW in MAN (OP-201, Step 8.2.3.2.a)

Standard: Candidate places FC-605 in manual by depressing the MAN pushbutton on the controller and observing that the MAN light is illuminated and the AUTO light is extinguished.

Examiners Note:

Comment:

J Performance Step: 2 START the Standby RHR Pump (OP-20i, Step 8.2.3.2.b)

Standard: Candidate starts RHR Pump A by placing the START I STOP control switch to the START position and observing that the RED on indication is illuminated and the GREEN off indication is extinguished.

Examiners Note:

Comment:

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 3 VERIFY proper operation of RHR Pump previously started on Step 8.2.3.2.b (OP-201, Step 8.2.3.2.c)

Standard: Candidate determines that RHR Pump A is operating properly by observing that the proper indication is received, no annunciators are received.

Examiners Note: When RHR Pump A is started, RHR relief valve RHR-706 opened and is relieving to the PRT. The candidate should note that PZR level is lowering.

Comment:

Performance Step: 4 STOP the previously running RHR Pump (OP-201, Step 8.2.3.2.d)

Standard: Candidate stops RHR Pump B by placing the START I STOP control switch to the STOP position and observing that the GREEN off indication is illuminated and the RED on indication is extinguished.

Examiners Note:

Comment:

Performance Step: 5 After RHR flow has stabilized as indicated on FI-605, PLACE FC-605, RHR HX BYPASS FLOW, in AUTO AND CHECK FCV 605 for proper operation (OP-201, Step 8.2.3.2.e)

Standard: Candidate places FC-605 in AUTO by depressing the AUTO pushbutton on the controller and observing the AUTO light illuminated and the MAN light extinguished.

Examiners Note: Candidate will determine that RCS inventory is lowering and enter AOP-020, Loss of Residual Heat Removal (Shutdown Cooling)

Comment:

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 6 Check RCS Level LESS THAN -72 INCHES (69% FULL RANGE RVLIS) (Step 1)

Standard: Candidate determines that RCS level is above -72 inches by observing RCs inventory in the PZR and transitions to Step 1 RNO and proceeds to Step 3.

Examiners Note:

Comment:

Performance Step: 7 Make PA announcement for procedure entry (Step 3)

Standard: Candidate makes the PA announcement by using an available PA handset and announcing that AOP-020 has been entered due to lowering RCS inventory.

Examiners Note:

Comment:

NOTE FRP-S.1 is NOT applicable for this event unless directed by the CSFSTs.

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 8 From the RTGB, verify reactor tripped as follows: (Step 4)

• Reactor Trip Main and Bypass Breakers OPEN

• Rod Position Indication ZERO

• Rod Bottom Lights - ILLUMINATED Standard: Candidate verifies that the reactor trip breakers are open by the GREEN open lights illuminated on the reactor trip breakers and no indication available on the reactor trip bypass breakers due to the breakers being racked out with the fuses removed.

Examiners Note: Rod position indication and rod bottom lights are extinguished due to the rod control system being de-energized with the plant in Mode 5.

Comment:

Performance Step: 9 Check PZR PORV Failed open from loss of power or malfunction (Step 5).

Standard: Candidate determines that both PZR PORVs are closed by observing the GREEN closed lights illuminated on PCV-455C and 456. Proceeds to RNO and Step 7.

Examiners Note:

Comment:

Performance Step: 10 Check RCPs Any running (Step 7)

Standard: Candidate determines that 1 of the RCPs is operating by observing the RED on light above the RTGB control switch for the RCP.

Examiners Note:

Comment:

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 11 Check RCP No. 1 Seal DIP Less than 210 PSID. (Step 8)

Standard: Candidate determines that all RCP No. 1 seal D/P are greater than 210 PSID by observing PI-i56A, PI-155A and Pl-i54A.

Candidate proceeds to Step 8 RNO.

Examiners Note:

Comment:

Performance Step: 12 Observe the NOTE prior to Step 10 and Go To Step 10. (Step 8 RNO)

Standard: Candidate observes the NOTE prior to Step 10 anf proceeds to Step 10.

Examiners Note:

Comment:

NOTE The RCS level trend should be carefully evaluated. A loss of RCS inventory as a result of a failed open PZR PORV that has been closed should result in a transition to Section E.

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 13 Check RCS level Lowering (Step 10)

• Pressurizer Level OR

• RCS loop standpipe level OR

• RVLIS OR

• Refueling Cavity Watch report.

Standard: Candidate determines that PZR level is lowering by observing PZR level recorder LR-459 Pen 1 and/or LI-459A, 460, 461 or 462.

Examiners Note:

Comment:

q Performance Step: 14 Verify all letdown flowpaths isolated as follows: (Step 11)

• LCV-460A and B, LTDN LINE STOP valves Closed.

• HIC-142, PURIFICATION FLOW controllerAdjusted to 0%.

• HIC-i 37, EXCESS LTDN FLOW controller Adjusted to 0%.

• CVC-387, EXCESS LTDN STOP Closed.

Standard: Candidate verifies that the control switches for LCV-460A and B and CVC-387 are placed to the closed position and the GREEN closed indication is illuminated.

Candidate verifies that the pots for HIC-142 and HIC-137 are rotated in the counterclockwise direction until the pot will no longer turn and the indication is showing 0%.

Examiners Note: LCV-460A and B are both controlled by a single control switch.

Comment:

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 15 Check Charging Pump status All stopped (Step 12).

Standard: Candidate determines that 2 Charging Pumps are running by observing the RED on status lights illuminated and proceeds to Step 12 RNO. Candidate raises the speed on the running Charging pumps to maximum by selecting manual on the pump speed controllers and depressing the UP pushbutton until the speed indicators indicate 100%.

Candidate proceeds to Step 17.

Examiners Note:

Comment:

Performance Step: 16 Check RCS Level Lowering (Step 17)

Standard: Candidate determines that PZR level is lowering by observing PZR level recorder LR-459 Pen 1 and/or Ll-459A, 460, 461 or 462.

Examiners Note:

Comment:

Performance Step: 17 Start one additional Charging Pump (Step 18)

Standard: Candidate determines that no additional charging pumps are available and proceeds to Step 24 from the RNO step.

Examiners Note:

Comment:

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 13 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 18 Check RCS temperature prior to event start Less than or equal to 200°F (Step 24)

Standard: Candidate determines that RCS temperature was less than 200°F when the event occurred by observing TR-410, TR-413 and/or Core Exit Thermocouples.

Examiners Note:

Comment:

J Performance Step: 19 Stop RHR Pumps (Step 25)

Standard: Candidate stops the running RHR pump by placing the control switch to the STOP position and observing the GREEN off lights illuminated for both of the RHR pumps.

Examiners Note:

Comment:

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 1 1 of 13 Form ESC-1 PERFORMANCE INFORMATION q Performance Step: 20 Isolate RHR by closing the following valves: (Step 26)

• RHR-750, RHR LOOP SUPPLY

• RHR-751, RHR LOOP SUPPLY

• RHR-744A, RHR COLD LEG (NJ

• RHR-744B, RHR COLD LEG (NJ Standard: Candidate isolates RHR system by placing the control switches for the following valves in the closed position and observing the GREEN closed indication illuminated.

• RHR-750 and 751, RHR LOOP SUPPLY

• RHR-744A and 744B, RHR COLD LEG INJ Examiners Note:

Comment:

q Performance Step: 21 Verify All RCPs - STOPPED (Step 27)

Standard: Candidate stops the running RCP by placing the control switch to the STOP position and observing the GREEN off lights illuminated for all of the RCPs.

Examiners Note:

Comment:

END OF TASK Terminating Cue: When PZR level is stable or increasing: Evaluation on this JPM is complete.

STOP TIME:

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 12 of 13 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM E Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1 I

Appendix C Page 13 of 13 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• The plant is in Mode 5.

• RHR is in service for core cooling.

• Charging Pump A is cleared and tagged.

INITIATING CUE: You are the RO. The CRS has directed you to swap to RHR Pump A in service lAW OP-201, Section 8.2.3 to equalize run time on the pumps.

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

Appendix C Page 13 of 13 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• The plant is in Mode 5.

• RHR is in service for core cooling.

• Charging Pump A is cleared and tagged.

INITIATING CUE: You are the RO. The CRS has directed you to swap to RHR Pump A in service lAW OP-201, Section 8.2.3 to equalize run time on the pumps.

2011-2 NRC JPM E NUREG 1021, Revision 9, Supplement 1

I Section 8.2.3 CONTINUOUS USE Page 1 of 2 IMT e

in the Core Cooling Mod 8.2.3 Switching RHR Pumps

1. Initial Conditions verified to be

a. This revision has been le.

the latest revision availab ction 4.0 have been

b. The prerequisites of Se -

completed.

2. Instructions BYPASS FLOW in

a. PLACE FC-605, RHR HX MAN.

R Pump. A I B

b. START the Standby RH (Circle one) n of RHR Pump

c. VERIFY proper operatio p 8.2.3.2.b.

previously started on ste B

OP the pre vio us ly run ning RHR Pump. A /

d. ST (Circle one) ized as indicated on After RHR flow has stabil ,

e. RHR HX BYPASS FLOW FI-605, PLACE FC-605, r FCV-605 for prope in AUTO AND CHECK operation.

FC-605 AUTO ERATION FCV-605 PROPER OP Page 18 of 36 Rev. 64 OP-201 I

Section 8.2.3 CONTINUOUS USE Page 2 of 2 INIT CAUTION al per running 7C an d RH R- 75 7D are open, 3750 gpm tot eded, except When both RHR-75 8A an d FI -60 8B shall NOT be exce 5, FI -60 s may be pump as read from FI-60 oved test procedures for which total flowrate appr as allowed/required by e pu mp or 8400 gpm for two pu mps.

gp m for on as high as 4200 increase th an 2, 80 0 gp m have been shown to le ss itions RHR pump flowrates of ns an d sh ou ld be av oided when plant cond uatio CR 91-078) pressure and flow fluct du rin g rec irculation operation. (A NO T ap ply permit. This does RHR Flow AD JU ST FC -60 5 in AUTO to maintain f.

3500 to 3750 GPM.

,NrneM2& -e Performed by:

Date Approved by: Shift Manager Page 19 of 36 Rev. 64 OP-201

CONTINUOUS USE T, UNIT NO. 2 AM ELECTRIC PLAN H. B. ROBINSON STE NUAL PLANT OPERATING MA VOLUME 3 PART 5 AB NO RM AL OP ERATING PROCEDURE AOP-020 DOWN COOLING)

SS OF RE SID UA L HEAT REMOVAL (SHUT LO REVISION 32 Page 1 of 130

n 32 AOP-020. Revisio of Ch an ge s PRR 432553 Summary SSO to SM ocedure, changed General: Throughout the pr ditorial) and CR85 to CRS (E crease and gh ou t th e pr oc edure, changed in Throu d lower.

cr ea se to va ria tions of raise an de (Editorial) menclature ocedure, added no Throughout the pr and valves.

sure instruments for flow and pres 0310)

(Editorial) (PRR 43 cooldown ocedure, added a Throughout the pr ed e stablish ps which stat rate limit to ste 0310) cooldown. (PRR 43 entry ument bus to the Added loss of instr Bus 6 or Entry ss of Instrument Conditions conditions. A lo mediate may not have an im Instrument Bus 8 adversely eration but will affect on RHR op io n.

d HIC-758 operat affect FCV-605 an Main Body ith a failed ved th e ac tio ns associated w Re mo power to Steps 5 sult of a loss of open PORV as a re and made the

& 6 m OLD step 5 RNO PT-500/PT-501 fro RNO to close ps. Provided an action into two ste lve. (PRR 383281) the PORV Block va and a C/A eck RCPs running Steps 7. Added steps to ch g RC Ps if pping runnin 8, & 9 step to support sto av ai la bl e.

d/p is not insufficient seal (PRR 431685) that the ert the operator Added a note to al of mass Note 10 resulted in a loss failed open PORV , the the PORV is closed from the RCS. If io n E.

be made to Sect transition should ishing boric detail for establ Step 13 Added additional R 430310) acid addition. (PR Page 2 of 130 AOP-020 Rev. 32

n 32 AOP-020. Revisio an ge s PR R 432553 Summary of Ch Continued d)

Main Body (Continue regarding to the steps Steps 18 Added additional pumps.

&21 sLarLing charging st and provided p to state adju Steps 28a Modified the ste a minimum VCT vel. Maintaining RNO & 30a a minimum VCT le within the ain Charging Flow level will maint 10)

RNO pacity. (ERR 4303 makeup system ca two steps.

th e ste p w ith two actions into Step 28c Split 430310)

RNO (Editorial) (PRR Section A ors that it remind the operat Added a note to fill the Note 4 to completely re may be necessary Thermocouples before Core Exit Reactor Vessel (PRR 293036) start to lower.

mp RUNNING Verify one SI Pu Changed step to co mm ents from Step lib St ar t on e SI Pu mp based upon from and 12b (ERR 240036) a CDBI inspection.

the first have SI-866B be Changed step to upon Step 12c g Injection based choice for Hot Le rs us Lo op 3. which is op 2 ve injection into Lo ts to the RCS.

rge Line connec where the Pzr Su (PRR 293076) binding.

for RHR Pump Air Step 21 Added indications (ERR 430310)

Section B into step 4 rtions of step 3 4 Incorporated po the SEP Gate Step ents for closing so the requirem (PRR 264089) e same step.

Valve are in th if SFP Lo Refer to AOP-036 5 New step added to 51 67 )

Step ceived. (PRR 37 Level Alarm is re ing cavity ded th e va lu es for normal refuel Step 20 Ad (PRR 430310) level to the step.

Page 3 of 130 AOP-020 Rev. 32 I

n 32 AOP-020. Revisio an ge s PR R 432553 Summary of Ch Continued d)

Section B (Continue binding.

for RHR Pump Air Step 22 Added indications (PRR 430310)

Section C 2

erator that LOOP Ne w No te to remind the op R 29 30 76 )

Note 7 n is preferred. (PR Hot Leg Injectio PZR Manway removed Ad ded PZ R Safety Valve or PO RV co uld be Step 7a conditions, a based upon plant ndition.

RNO in this plant co under maintenance (PRR 430310)

Pump RUNNING to Verify one SI an ge d ste p ts Step 7c RNO Ch sed upon commen fro m S ta rt one SI Pump ba 36 )

and lOa ection. (PRR 2400 from a CDBI insp rst 6B be listed fi RN O Ch an ge d step to have SI-86 in je ct io n Step 7d ction based upon for Hot Leg Inje ich is where the into Loop 2 versus Loop 3, wh line connec ts to the RCS.

Pressurizer Surge (PRR 293076) oved.

or PZR Manway rem Ad ded PZR Safety Valve uld be Step 9 itions, a PORV co ba sed upon plant cond nd iti on .

RNO in this plant co under maintenance (PRR 430310) ing.

RHR Pump Air bind 15 Ad ded indications for Step (PRR 430310) the GP in effect to Ad ded a s directed by the Step 20e )

step. (PRR 430310 Section P mp RUNNING Verify one SI Pu Step 12b Changed step to up on co mments l Pump based and 13b from Start oneS 00 36 )

ection. (PRR 24 from a CDBI insp Page 4 of 130 AOP-020 Rev. 32

AOP-020, Revision 32 432553 Summary of Changes PRR Continued Section D (Continued) choice SI-866B be the first Changed step to have n into Step 13c n based upon injectio for Hot Leg Injectio the Pzr 3, which is where Loop 2 versus Loop 076) to the RCS. (PRR 293 Surge Line connects Based limits to the step.

Step 23 Added cooldown rate al cir cu lation.

n the po ten tia l to be in natur upo (PRR 430310) g.

RHR Pump Air bindin Step 24 Added indications for

& 37 (PRR 430310)

PC-li5 dance for adjusting Step 26e Added additional gui re for RCP limit of pressu

& 40e to address the lower operation. (PRR 430310) the the GP in effect to Step 43d Added as directed by step. (PRR 430310)

Section E PP check for a PORV LTO Step 2 Added a new step to 383281) being defeated. (PRR pplies states the power su Note 3 This is a note that 281 )

1. (PRR 383 for PT-500 and PT-50 to make ed to the procedure These steps were add when Steps 3 system gets restored sure that the LTOPP me nts.

& 4 the pressure instru power is restored to (PRR 383281) regarding additional clarity Note 6 New note to provide step 6.

describe ng to more clearly Revised the step wordi provide Step 6 p. RNO changed to the intent of the ste closure.

action for OMM-033 nt bus to the step.

Step 11 Added loss of instrume Page 5 of 130 AOP-020 Rev. 32

p n 32 AOP-020, Revisio Ch an ge s PR R 432553 Sunmiary of Continued d)

Section B (Continue step 43 ge d th e tra ns ition in the RNO to Ch an R 383281)

Step 13 le comments. (PR RNO based upon multip mpressors ensure that IA Co New step added to prevent Step 14 rs are restored to and Battery Charge or DC.

m a loss of air future problems fro If a ch ar gi ng was Comment.

CDBI Inspection 24 00 36 )

started. (PRR running, it is re RHR Pump is is no te cl ar ifi es what an IDLE Th )

Note 15 steps. (PRR 432553 in the following an IDLE RHR ort restoration of Steps 15, These steps supp or GP007.

igned per GP002 16, & 17 Pump if one is al (PRR 432553) ndby RHR Pump ns to start a sta Step 18f Added instructio 8103)

RNO in the step. (PRR 39 automatic de d gu id an ce to restore FC-605 to Step lSh Ad (PRR 455770) en HCV- 142 to close and reop Step 18d New steps added 6797) and 18j (HIC-142) (PRR 21 the RNP to strument bus to Added loss of in rth er actions Step 21 s where the fu support condition ar m was not e low flow al are needed but th illuminated.

power supply tes regarding the Added multiple no troller, Notes 24 ation, FC-605 Con for FC-605 M/A St ses

8. The END addres FT-605. and HIC-75 (PRR 43 10 03 uments.

powering the instr PRR 408570) wer available d in st ru ct io ns to check for po Ad de tions to Step 24a nt ro lle rs an d indicator and ac to co nergized.

mponents are de-e perform if the co R 430310)

(PRR 408570, PR Page 6 of 130 AOP-020 Rev. 32

n 32 AOP-020, Revisio ges PRR 432553 Summary of Chan Continued d)

Section E (Continue mode along ste p to re st or e FCV-605 to auto Ne w rs.

Step 25 r other controlle with a prornpL fo tential means the step as a po Step 29 Added HIC-758 to Temperature.

to maintain RCS ich will ste p to im pl ement DSP-009, wh Adde d a with FT-605 Step 43d id e RH R To ta l flow indication RNO prov R 383281) de-energized. (PR auto.

restore FC605 to Step 52 Added guidance to on e SI Pump RUNNING from ify p to V er m a CDBI Step 63b Changed ste d upon comments fro e SI Pu mp ba se and 64b Start On 240036) inspection. (PRR rst choice p to ha ve SI-866B be the fi Change d ste jection into Step 64c In je ct io n based upon in for Ho t Le g here the Pzr Surge op 2 ve rs us Lo op 3, which is w Lo 3076) the RCS. (PRR 29 Line connects to Attachment 1 e that RHR-754A re step 3 to stat Added a note befo rod and ca re must be taken ed by a re ac h is operat 409565) t position. (PRR to ensure correc Attachment 2 e that RHR-754B be fo re step 3 to stat Ad de d a no te re must be taken reach rod and ca is operated by a 409565) t position. (PRR to ensure correc Page 7 of 130 AOP-020 Rev. 32

n 32 AOP-020, Revisio ges PRR 432553 Summary of Chan Continued Attachment 3 the first choice p to have SI-866B be Ch an ge d ste injection into Step 6b ction based upon 14c for Hat Leg Inje ere the Pzr Surge and op 3, which is wh Loop 2 versus Lo 76) the RCS. (PRR 2930 Line connects to nway removed.

Valve or PZR Ma Step 8 Added PZR Safety PO RV cDuld be t conditions, a based upon plan t co ndition.

RNO ce in this plan under maintenan (PRR 430310) mp RUNNING from Verify one ST Pu Changed step to ents from a COBI Step 13b based upon comm and 14b Start one SI Pump 2i0036) inspection. (PRR Attachment 10 to support a new attachmenL Attachment 10 is se rv ice if RHR Pump for aligning an Idle 2 or GP-007.

ed per GP-00 the pump is idl (PRR 432553) d Attachments ment numbers an us Action Attach hA and 11B Updated Continuo chm en t 10 an d new sed upon new atta Step Numbers ba C/A steps.

Page 8 of 130 AOP-020 Rev. 32

Rev. 32 G)

UTDOWN COOLIN SS OF RE SID UA L HEAT REMOVAL (SH Page 9 of 130 AOP-020 LO I RESPONSE NOT OB TAINED I H STEP 1f INSTRUCTIONS

1. PURPOSE mitigate the th e in st ru ct ions necessary to provides RHR can be aligne d to This procedure itions for which R in al l co nd of RH R co ol ing for loss of RH Th is in cl udes loss provide shutdown cool in g. of Service Water ag e, lo ss of power, loss reasons such as RCS le ak and inadequate in g W ate r, RH R pump cavitation, ol or Component Co RHR cooling.

flo w or ab no rm al reductions in RHR is in and 6 when fuel is ap pl ic ab le in Modes 4, 5, This procedure the vessel.

S

2. ENTRY CONDITION of RHR lting in a loss en try fro m an y condition resu w or te mperature Direct vi ta tio n, ab normal RHR flo pump(s), RHR pum p ca loss of RCS in str um en t bu s, or excessive control, loss of for shutdown co oling.

ve nt or y w hi le RHR is aligned in her procedures:

the following ot As directed by level in the on ito rin g Sy stem, when a low AOP005, Radiatio n M VALVE open.

• an RC S le ak w ith the SFP GATE to 5FF exists due nction, resulting en t Co ol in g W ater System Malfu

• AOP-014, Compon hile in CSD.

the RHR Pumps w in stopping of F

i+/- less than 200° ce ss iv e Pr im ar y Plant Leakage,

• AOP-Ol6, Ex pacity.

eds Charging Ca and leakage exce Instrument Air str um en t A ir, if the loss of In

• AOP-017, Loss Of RHR.

fe ct ed co re cooling while on has af

- END -

I

Rev. 32 WN COOLING)

HEAT REMOVAL (SHUTDO Page 10 of 130 AOP-020 LOSS OF RESIDUAL I RESPONSE NOT OBTA INED I STEP H INSTRUCTIONS IF RCS Level becom es less than Check RCS Level LESS THAN LL RANGE

-72 inches (69% FU 1.

RANGE RVLIS) BOTH RHR 72 INCHES (69% FULL RVLIS). THEN ve rif y Pumps stopped.

Go To Step 3.

mps STOPPED Verify BOTH RHR Pu 2.

nt For

3. Make PA Announceme Procedure Entry NOTE FSTS.

directed by the CS applicable fDr this event unless FRP-S.1 is es NQ trip.

rify Reactor Ii the reactor do Opera tor to the

4. From The RTGB, Ve THEN dispatch an Tripped As Follows

m to Open Rod Drive MG Set Roo RS A ll B.

AND BYP REACTOR TRIP BREAKE REACTOR TRIP MAIN OPEN cation Rod Position indi ZERO Rod Bottom lights ILLUMINATED Go To Step 7 FAILED OPEN

5. Check PZR PORV -

WE R OR NALFUNCTTON FROM LOSS OF PO ock valve.

Close the PORV Bl Switch in

6. Place LTOPP Arming K

NORMAL

• RC535, PORV BLOC

• PT-500 - PZR PORV PCV-456 OR OR

• RC-536, PORV BLOCK

• PT-501 - PZR PORV PCV-455C prior to Observe the NOTE ANY RUNNING Step 10

7. Check RCPs -

Step 10 and Go To

I Rev. 32 UTDOWN COOLING)

L HEAT REMOVAL (SH Page 11 of 130 AOP-020 LOSS OF RESIDUA INSTRUCTIONS I RESPONSE NOT OBTA INED I f STEP_H LESS IF RCP No. 1 Seal DIP lowers to Check RCP No. 1 Se al DIP id, Th perform less than 210 ps 8.

THAN 210 P5 10 .

Step 9.

prior to Observe Che NOTE Step 10 Step 10 and Go To RCP(s)

9. Stop Any Running NOTE of RCS evaluated. A loss Le ve l tre nd sh ou ld be carefully th at ha s be en closed The RCS a fa ile d ope n PZR PORV sult of inventory as a re Section E.

re su lt in a transition to should NOT involve a IF he event does LOWERING: Inventory.

10. Check RCS Level -

continuing loss of cti on 5, Loss Of THEN Go To Se Pressurizer leve l erature Control.

• RER Flow Or Temp en stopped OR 1E RHR Pumps have be entory, due to loss of Inv e level

• RCS loop standpip Go To Step 11.

OR

• RVLIS OR Watch report

• Refueling Cavity Flowpaths

11. Verify All Letdown llo ws :

Isolated As Fo N LINE STOP

• LCV-460A & B, LTD Valves - CLOSED TION FLOW

• HIC-142, PURIFICA AD JUS TED TO 0%

Controller -

LTDN FLOW

• HIC-137. EXCESS r AD JUS TED TO 0%

Controlle -

LTDN STOP CVC-387, EXCESS CLOSED I

Rev. 32 DOWN COOLING)

AOP-020 LOSS OF RESIDUAL HEAT REMOVAL (SHUT Page 12 of 130

STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED I ALL Raise speed on the running

12. Check Charging Pump Status Charging Pump to maximum.

STOPPED Go To Step 17.

13. Estab1ih Charging Flow As Follows:

GREATER a. Perform the following:

a. Check VCT Level -

THAN 12.5 INCHES

1) Verify OPEN LCV-115B, EMERG MU TO CHG SUCT.

2) Verify CLOSED LCV-115C.

VCT OUTLET.

3) Go To Step 13.e.

b. Verify RCS makeup concentration set to value greater than current RCS boron.

FLOW

1) FCV-113A, BORIC ACID Controller - POT SET AT 10.0

2) FCV-113A. BORIC ACID FLOW Controller - IN AUTO LET

c. Verify LCV-115C, VOT OUT OPEN TO

d. Verify LCV-115B, EMERG MU CHG SUCT - CLO SED FLOW

e. Verify HIC-121, CHARGING Control ler - ADJ UST ED TO 0% (OPEN) 1 COLD f. Verify OPEN CVC-310A, LOOP

f. Verify CVC-31OB, LOOP 2 HOT LEG CHG .

LEG CHG - OPEN

1. Start One Charging Pump 22A

15. Observe charging flow on FI-1

16. Raise Speed On The Running Charging Pump To Maximum

Rev. 32 ING)

REMOVAL (SHUTDOWN COOL AOP-020 LOSS OF RESIDUAL HEAT Page 13 of 130 STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED still in LOWERING E the RHR System is AOP-016,

17. Check RCS Level -

service, THEN Go To nt Leakage.

Excessive Primary Pla Pump has IF the operating RHR THE N Go To Step 24.

been stopped, ps are Charging no other Charging Pum

18. Start One Additional available, THEN Go To Step 24.

Pump nning

19. Raise Speed On The Ru um Charging Pump To Maxim ll in the RHR System is sti Check RCS Level LOWERING Go To AO P-0 16,

20. service, THEN ma ry Pla nt Le akage.

Excessive Pri Pump has IF the operating RHR rfo Step 24.

been stopped, TEEN Co ps are Charging no other Charging Pum

21. Start One Additional available, THEN Go To Ste p 24.

Pump nning

22. Raise Speed On The Ru To Ma xim um Charging Pump ll in the RHR System is sti Check RCS Level LOWERING P-016,

23. service, THEN Go To AO nt Leakage.

Excessive Primary Pla wn LOCA.

e Prior To Go To AOP-033, Shutdo

24. Check RCS Temperatur LESS THA N OR EQUAL Event Start -

TO 200°F

25. Stop RHR Pumps g The

26. Isolate RHR By Closin Followin g Va lve s:

PPLY

• RHR-750, RHR LOOP SU PPLY

• RHR-751, RHR LOOP SU INJ a RHR-744A, RHR COLD LEG INJ

• RHR-744B, RHR COLD LEG Verify All RCPs STOPPED 27.

Rev. 32 DOWN COOLING)

L HEAT REMOVAL (SHUT Page 14 of 130 AOP-020 LOSS OP RESIDUA I f RESPONSE NOT OE TAINED I

STEP H INSTRUCTIONS RWST level lower s to 9%, TN Pump Suction wing:

Check Charging perform the follo

• 28.

ALIGNED TO VCT charging flow to

a. Adjust total GREATER l

maintain VCT leve THAN 20 INCHES.

LCV-ll5C, VCT

b. Verify OPEN OUTLET.

G ED LCV-115B, EMER

c. Verify CLOS MU TO CHG SUCT ED CVC-358, RWST

d. Verify CLOS SUCTION.

TO CHARGING PUMP ior to Step 31 Observe NOTE pr and Go To Step 31 ers to less than IF VCT level low LESS THAN perform

• 29. Check VCT Level 12.5 inches. THEN 12.5 INCHES Step 30.

ior to Step 31 Observe NOTE pr and Go To Step 31 mp Suction From

30. Align Charging Pu ws:

The RWST As Follo llowing:

GREATER a. Perform the fo vel

a. Check RWST le charging flow THAN 9% 1) Adjust total to maintain VC T level -

20 INCHES.

GREATER THAN prior to

2) Observe NOTE Step 31 an d Go To Step 31.

CVC-358, RNST TO

b. Verify OPEN

. verify OPEN CTION, prior

b. At the RTGB CHARGING PUMP SU MU TO CHG SUCT LCV-ll5E, EMERD to continuing.

LCV-ll5C, VCT

c. Verify CLOSED OUTLET

Rev. 32 LOSS OF RESIDUAL HEAT REMOVAL (SHUT DOWN COOLING)

AOP-020 Page 15 of 130 H STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED NOTE tain the CV Purge in service if The intent of this procedure is to main the Equipment Hatch is not installed.

31. Initiate CV Closure Using OMM-033, CV Closure

32. Dispatch An Operator To Open The Breakers For Containment Sump Pumps A and B:

• CV SUMP PUMP A - MCC-2

• CV SUMP PUMP B - MCC-1

Rev. 32 (SHUTDOWN COOLING)

AOP-020 LOSS OF RESIDUAL HEAT REMOVAL Page 16 of 130 H STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED NOTE able of being red filled if the RCS is cap The RCS Loops are conside eLa blished through ondary heaL sink can be pressurized such that a sec natural circulation.

CAUTION RCS Loop Standpipe result in inaccuracies in Changes in RCS pressure may indications.

nt Perform the following:

33. Check RCS Level Prior To Eve Start BELOW -36 INC HES

a. Implement the EALs.

b. Notify the SM STA that ALLachm ent 9, Pot ential Techni cal Spe cifi cati ons, is available for reference.

Head is

c. IF the Reactor Vessel removed, THEN Go To Sec tion B, Loss Of RHR Inv ento ry -

Vessel Head Off.

is

d. IF the Reactor Vessel Head ed JJJ the RCS Loop s insta].l NOT filled, THEN Go To Section C, Loss Of RHR Inventory - Vessel Head On.

e. the RCS Loops are filled.

Of THEN Go To Section 0, Loss RHR Invento ry - Lev el Sta ble Or Rising.

Rev. 32 AOP-020 LOSS OF RESIDUAL HEAT REMOVAL (SHUTDOWN COOLING)

Page 17 of 130 STEP H INSTRUCTIONS f I RESPONSE NOT OBTAINED

34. Perform the following:

a. Implement the EALs

b. Notify the SM Q STA that Attachment 9, Potential Technical Specifications, is available for reference

c. Go To Section A, Loss Of RHR While At Reduced Inventory

- END -

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01026100101 Task

Title:

CV Isolation Phase B and CV Spray JPM No.: 2011-2 NRC JPM F Alignment K/A

Reference:

026 A4.01 4.5 / 4.3 103 A2.03 3.5 /3.8 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

• The plant was operating at 100% RTP when a Large Break LOCA occurred.

• Automatic Reactor Trip and Safety Injection actuated.

• PATH-i has been implemented.

• Grid Location B-7, CV PRESS REMAINED BELOW 10 PSIG, has been answered as NO.

Task Standard: Align Phase B Isolation valves and CV Spray valves lAW Supplement B.

Required Materials: Supplement B, Phase B and CV Spray Component Alignment.

General

References:

PATH-i, Revision 22 Supplement B, Revision 41 Handout: NONE 2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Initiating Cue: The CRS has directed you to perform Supplement B to verify the Phase B and CV Spray components alignment.

Time Critical Task: NO Validation Time: 5 minutes 2Oii-2 NRC JPM F NUREG iO2i, Revision 9, Supplement i

Appendix C Job Performance Measure Form ES-C-I Worksheet SIMULATOR SETUP I. ResettolC-811

2. No SCN required.

3. Place simulator in RUN when directed by the examiner.

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 10 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with a check mark)

START TIME:

Performance Step: I Obtain a copy of the appropriate procedure.

Standard: Candidate obtains a copy of Supplement B, Phase B and CV Spray Component Alignment.

Examiners Note: EPP Foldouts and Supplements are located under the RTGB apron at 2 different locations, in the book holder with APP 001 1002 and in the book holder with APP-009 1010.

Comment:

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 10 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 2 To establish Phase B Containment Isolation, verify the following valves CLOSED (Supplement B, Step 1)

a. RCP Cooling

• CVC-381, SEAL WTR RTRN ISO

• FCV-626, THERM BAR FLOW CONT

• CC-735, THERM BAR OUT ISO

• CC-716A, CCWTO RCP ISO

• CC-716B, CCWTO RCP ISO

• CC-730, BRG OUTLET ISO Standard: Candidate determines that valves CVC-381, FCV-626, CC-735, CC-716A, CC-716B and CC-730 are closed by observing the GREEN closed indication for the valves illuminated and the RED open indication extinguished.

Examiners Note: Candidate may use the Containment Isolation Phase B status panel to verify the valves in the proper position except for valve FCV-626, which must be verified using the RTGB indication.

Candidate may use the Containment CSFST indication for Phase B Isolation Valve Status to determine the valve positions. This information is obtained by paging over to the Containment CSFST and using the UP or DOWN arrows to access the applicable panel.

Comment:

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 10 Form ES-C-i PERFORMANCE INFORMATION q Performance Step: 3 To establish Phase B Containment Isolation, verify the following valves CLOSED (Supplement B, Step 1)

b. MSIV AND MSIV BYPs CLOSED-Standard: Candidate observes the RTGB indication for MSIV valves V1-3A, Vi -3B and Vi -3C and observes that the RED open indication is illuminated and the GREEN closed indication is extinguished.

Candidate will place the control switches for the MSIV valves Vi -

3A, V1-3B and Vi-3C to the close position and observe that the GREEN closed indication is illuminated and the RED open indication is extinguished.

Candidate will observe that NO RTGB indication is available for the MSIV Bypass valves MS-353A, MS-353B and MS-353C exists due to the breakers for the valves being in the locked open position.

Examiners Note: Candidate may use the Containment CSFST indication for MSIV and MSIV Bypass valve positions. The MSIV Bypass valves MS-353A, MS-353B and MS-353C will show INVALID due to the breakers being locked open for the valves.

The MSIV Bypass valves MS-353A, MS-353B and MS-353C breakers are normally locked open with NO RTGB indication available, If any of the valves are open, OP-923, CV Integrity, attachment will be in place tracking the out of position CV Isolation valve.

Comment:

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 10 Form ES-C-i PERFORMANCE INFORMATION q Performance Step: 4 To establish CV Spray, perform the following: (Supplement B, Step 2)

a. Verify valves positioned as follows:

• Sl-844A, PUMP A INLET OPEN

• SI-844B, PUMP B IN LET OPEN

• SI-845A, SAT DISCH OPEN

• Sl-845B, SAT DISCH OPEN

• Sl-845C, SAT THROTTLING THROTTLED TO APPROXIMATELY 12 GPM

• SI-880A, PUMP A DISCH OPEN

• SI-880B, PUMP A DISCH OPEN

• S 1-88CC, PUMP B DISCH OPEN

• Sl-880D, PUMP B DISCH OPEN Standard: Candidate determines that valves Sl-844A, SI-844B, Sl-845B, SI 880A and Sl-880B are open by observing the RTGB valve indication RED open lights are illuminated and the GREEN closed indication is extinguished.

Candidate determines that valves SI-845A, SI-880C and Sl-880D are closed by observing the GREEN closed indication illuminated and the RED open indication extinguished. He will place the control switches for the valves to the OPEN position and verify that the RED open indication is illuminated and the GREEN closed indication is extinguished.

Candidate determines that Spray Additive Flow is greater than 12 GPM by observing FI-949, Spray Additive Flow, and throttles flow to 12 GPM by momentarily placing the control switch for valve SI 845C, SAT Throttling, in the CLOSE position until the desired flow is established.

Examiners Note: Candidate may use the Containment Spray status panel to verify that valves SI-880A, SI-880B, Sl-880C and SI-880D are open.

Candidate may use the Containment CSFST indication for Containment Spray Status to determine the valve positions.

This information is obtained by paging over to the Containment CSFST and using the UP or DOWN arrows to access the applicable panel.

Comment:

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 10 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 5 To establish CV Spray, perform the following: (Supplement B, Step 2)

b. Return to procedure and step in effect.

Standard: Candidate has completed the actions in Supplement B and should report the completion of the supplement to the CRS.

Examiners Cue: Respond by acknowledging that Supplement B has been completed Comment:

END OF TASK Terminating Cue: When the candidate reports that Supplement B has been completed, evaluation on this JPM is complete.

STOP TIME:

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 10 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM F Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 10 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• The plant was operating at 100% RTP when a Large Break LOCA occurred.

• Automatic Reactor Trip and Safety Injection actuated.

• PATH-i has been implemented.

• Grid Location B-7, CV PRESS REMAINED BELOW 10 PSIG, has been answered as NO.

INITIATING CUE: The CRS has directed you to perform Supplement B to verify the Phase B and CV Spray components alignment.

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 10 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• The plant was operating at 100% RTP when a Large Break LOCA occurred.

• Automatic Reactor Trip and Safety Injection actuated.

• PATH-i has been implemented.

• Grid Location 8-7, CV PRESS REMAINED BELOW 10 PSIG, has been answered as NO.

INITIATING CUE: The CRS has directed you to perform Supplement B to verify the Phase B and CV Spray components alignment.

2011-2 NRC JPM F NUREG 1021, Revision 9, Supplement 1

Rev. 41 EPP-Supplements SUPPLEMENTS Page 20 of 102 CONTINUOUS USE Supplement B Phase B And CV Spray Component Alignment (Page 1 of 1)

1. To establish Phase B Containment Isolation, verify the following valves - CLOSED

a. RCP Cooling

• CVC-381, SEAL WTR RTRN ISO

• FCV-626, THERM BAR FLOW CONT

• CC-735, THERM BAR OUT ISO

• CC-716A, CCW TO RCP ISO

• CC-716B, CCW TO RCP ISO

• CC-73O, BRG OUTLET ISO

h. MSIV AND NSIV BYPs - CLOSED

2. To establish CV Spray, perform the following:

a. Verify valves positioned as follows:

• 5I-844A, PUMP A INLET - OPEN

• SI-844B, PUMP B INLET - OPEN

• SI-845A, SAT DISCH - OPEN

• SI-845B, SAT DISCH - OPEN

• SI-845C, SAT THROTTLING - THROTTLED TO APPROXIMATELY 12 GPM

• SI-8SOA, PUMP A DISCH - OPEN

• SI-880B, PUMP A DISCH - OPEN

• SI-88OC, PUMP B DTSCH - OPEN

• SI-880D, PUMP B DISCH - OPEN

b. Return to procedure and step in effect.

- END -

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01015100501 Task

Title:

Remove Source Range Instrument JPM No.: 2011-2 NRC JPM G From Service KlA

Reference:

015A4.03 3.8/3.9 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

• The plant is in Mode 3 at 547°F.

• Source Range Channel N-31 has failed and has been declared inoperable by the CRS.

Task Standard: N-31 removed from service lAW OWP-0i 1, NI-S.

Required Materials: OWP-01 1, NI-S General

References:

OWP-01 1, Nuclear Instrumentation, Revision 22 Handouts: OWP-01 1, NI-S Initiating Cue: The CRS has directed you to remove N-31 from service lAW OWP-01 1, NI-S.

Time Critical Task: NO Validation Time: 6 minutes 2011-2 NRC JPM G NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet SIMULATOR SETUP

1. ResettolC-8i2

2. No SCN required.

2011-2 NRC JPM G NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 7 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with a check mark)

START TIME:

Performance Step: I Remove Nl-31 from ERFIS SCAN: NINOO31A REMOVED (OWP-Oi1, NI-5, 1 st Step)

Standard: Candidate removes the point from ERFIS scan by performing the following steps:

Delete the ERFIS point from scan

• Access the Delete function by typing DR (Delete/Restore).

• Click on DELETE SCAN

• Enter NINOO31A Examiners Note:

Comment:

q Performance Step: 2 AUDIO COUNT RATE CHANNEL CHANNEL SELECTOR switch: Selected to SR 32 (OWP-Oi i, NI-5, 2 nd Step)

Standard: Candidate places the Audio Count Rate Channel Selector switch to the SR 32 position and notes the proper audio count rate.

Examiners Note: This switch must be pulled out to rotate between the different positions.

Comment:

2011-2 NRC JPM G NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 7 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 3 START UP RATE CHANNEL SELECT Switch Selected to NI____ (OWP-Oi i, Nl-5, 3rd Step)

Standard: Candidate determines that the Startup Rate Channel selector switch is NOT selected to N-3i.

Examiners Note: The Startup Rate Selector switch is normally selected to one of the Intermediate Range Channels N-35 or N-36 and is NOT affected by the Source Range failure.

Comment:

q Performance Step: 4 LEVEL: TRIP Switch: BYPASS (OWP-Oi 1, Nl-5, 4th Step)

Standard: Candidate rotates the Level Trip Bypass switch on the N-3i drawer front to the Bypass position.

Examiners Note: APP-005-D4, NIS TRIP I DROP ROD BYPASS, will be received when the level trip switch is positioned to the bypass position.

Level Trip Bypass will be illuminated on the front of the N-31 drawer.

Comment:

2011-2 NRC JPM G NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 7 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 5 NIS TRIP BYPASS Nl-31 Status Light: ILLUM (OWP-Oi 1, Nl-5, 5th Step)

Standard: Candidate observes that the 2X2 status light on the RTGB is illuminated.

Examiners Note: NIS TRIP BYPASS Nl-31 Status Light was illuminated when the N-31 Bypass switch was selected to Bypass position.

Comment:

.J Performance Step: 6 HIGH FLUX AT SHUTDOWN Switch: BLOCK (OWP-O1 i, Nl-5, 6th Step)

Standard: Candidate rotates the High Flux at Shutdown switch on the N-3i drawer front to the BLOCK position.

Examiners Note: APP-005-B1, HI FLUX AT SHUTDOWN ALARM BLOCK, annunciator will be received on the RTGB.

Comment:

END OF TASK Terminating Cue: When Source Range Channel N-31 has been removed from service lAW OWP-O11, NI-5, evaluation on this JPM is complete.

STOP TIME:

2011-2 NRC JPM G NUREG 1021, Revision 9, Supplement I

Appendix C Page 6 of 7 Form ES-C-I VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM G Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM G NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 7 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• The plant is in Mode 3 at 547°F.

• Source Range Channel N-3i has failed and has been declared inoperable by the CRS.

INITIATING CUE: The CRS has directed you to remove N-31 from service lAW OWP-Oi1, NI-5.

2011-2 NRC JPM G NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 7 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• The plant is in Mode 3 at 547°F.

• Source Range Channel N-3i has failed and has been declared inoperable by the CRS.

INITIATING CUE: The CRS has directed you to remove N-31 from service lAW OWP-Oii, NI-S.

201 1-2 NRC JPM G NUREG 1021, Revision 9, Supplement 1

CONTINUOUS USE OWP

Title:

NI-5 Page 1 NI-31, Source Range

1. This revision has been verified to be the latest revision available.

(Print)

Name Signature -

Date

2. System: NI Work Request No:

3. Component: NI-31, Source Range

4. Scope of Work:

Perform maintenance on Nuclear Instrument Nl-31.

5. Testing required on redundant equipment prior to rendering component inoperable:

N/A

6. Precaution:

1) Refer to ITS Table 3.3.1-1 for Source Range applicability and operability requirements when not in the Refueling condition (MODE 6)

2) Reference ITS [CO 3.9.2 during Refueling Operations (MODE 6).

3) Removal of control power fuses below P-6 will cause a reactor trip signal.

4) This OWP has been screened in accordance with PLP-037 criteria and determined to be a Case Three activity.

7. Valve/Breaker/Switch lineup has been completed.

Signature Date

8. Clearance Issued (If applicable) Clearance No:

9. l&C Maintenance lineup complete. N/A / N/A Signature Date

10. Clearance removed and Valve/Breaker!

Switch lineup restored to normal. /

Signature Date II. Source Range Nl-31 has been declared operable.  !

Signature Date OWP-01 I Rev. 22 Page 20 of 27

CONTINUOUS USE OWP

Title:

NI-5 Page 2 °f__Z_

VALVE, BREAKER, SWITCH LINEUP COMPONENT POSITION FOR RESTORED DESCRIPTION MAINTENANCE POSITION SOURCE RANGE CHANNEL N 1-31 INIT INIT REMOVE Nl-31 from ERFIS SCAN: NINOO3IA REMOVED RESTORED AUDIO COUNT RATE CHANNEL CHANNEL -

SELECTOR Switch Selected to SR 32 START UP RATE CHANNEL SELECT Switch*

NI LEVEL TRIP Switch BYPASS NORMAL NIS TRIP BYPASS NI-31 Status Light ILLUM EXTNG NORMAL IF SHUTDOWN HIGH FLUX AT SHUTDOWN Switch BLOCK OR BLOCK Switch should be selected to an NI which is NOT removed from service.

OWP-O1 1 Rev. 22 Page 21 of 27

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01000106705 Task

Title:

Respond To A Loss Of CCW To The JPM No.: 2011-2 NRC JPM H RCP Motor Coolers K/A

Reference:

008 K1.02 3.3/3.4 008 K3.03 4.1/4.2 026 AK3.03 4.0/4.2 Examinee: NRC Examiner: N/A Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Plant is at 100% RTP.

No equipment is out of service.

You are the Reactor Operator.

Task Standard: Actions taken to ensure the RCPs are NOT damaged. AOP-014, Section D actions completed with the exception of referring to Tech Specs and implementing the EALs.

Required Materials: AOP-014 Main Body and Section D General

References:

APP-001-A8, CCWto CRDM LO FLOW APP-001-B1, RCP BRG COOL WTR LO FLOW APP-001-Di, RCP THERM BAR COOL WTR LO FLOW AOP-014, Section D CCW System Low Flow OR High Temperature 201 1-2 NRC JPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Handouts: AOP-0i4 Main Body and Section D Initiating Cue: Respond to plant events.

Time Critical Task: NO Validation Time: 6 Minutes SIMULATOR SETUP

1. ResettolC-813

2. Open SCN: 008_JPM_NRC_H

3. Place simulator in run when directed by the examiner.

4. Execute the CCW failure when directed by the examiner.

2011-2 NRC JPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 10 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk START TIME:

Performance Step: I Candidate refers to APP-001-A8, Bi and/or Dl.

Standard: Candidate observes RCP bearing temperatures are rising and valve CC-716B indicates closed.

Candidate takes action for loss of CCW to RCPs and enters AOP-014, CCW System Malfunction Examiners Note:

Comment:

AOP-014, MAIN BODY Performance Step: 2 Implement The EALs. (Step 1)

Standard: Candidate notifies the SM of EAL implementation.

Examiners Note: Candidate is NOT responsible for implementing the EALs Examiners Cue: Respond as the SM that you will implement the EALs.

Comment:

2011-2 NRC JPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 10 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 3 Make PA Announcement for procedure entry (Step 2).

Standard: Candidate makes PA announcement for entry into AOP-014.

Examiners Note:

Comment:

NOTE A loss of inventory may be indicated by a report of leakage or lowering of surge tank level.

CCW Pump discharge pressure less than 78 psig will cause an alarm.

CCW low flow is defined as less than 2200 gal per pump.

CCW high temperature is defined as greater than 105°F or greater than 125°F if in Mode 3.

Performance Step: 4 Go To Appropriate Section For Indicated Malfunction (Step 3)

Standard: Candidate proceeds to AOP-014, Section D based on high temperature or low flow.

Examiners Note:

Comment:

201 1-2 NRCJPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 10 Form ES-C-i PERFORMANCE INFORMATION AOP-014, Section D Performance Step: 5 Monitor RCP temperatures using ERFIS Group Display RCP LOG or RCP Temperature Recorder TR-448 (Step 1)

Standard: Candidate observes rising motor bearing temperatures by displaying GD RCP LOG on ERFIS or monitors TR-448.

Examiners Note: Candidate may notice CC-716B closure at any time and may dispatch an Operator for local valve operation.

BOOTH OPERATOR If dispatched to locally open valve CC-716B, report the valve CUE: is stuck on the closed seat and will not open manually.

Comment:

Performance Step: 6 Check APP-001-Bi RCP BRG COOL WTR LO FLOW extinguished. (Step 2)

Standard: Candidate observes that APP-00i -Bi, RCP BRG COOL WTR LO FLOW is NOT extinguished and goes to RNO Step 2.

Examiners Note:

Comment:

2011-2 NRC JPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 10 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 7 Verify CC-7i6A, CC-716B, and CC-730 open: (RNO Step 2.)

Standard: Candidate verifies CC-716A and CC-730 open and attempts to open CC-716B. Determines that CCW flow CANNOT be restored and proceeds to Step 4.

Examiners Note: The failure of CC-716B may have already been addressed.

Booth Operator Cue: See JPM Performance Step 5 for local operator actions if directed to manually open valve CC-716B.

Comment:

Performance Step: 8 Determine if reactor trip is required as follows:

Check Reactor Critical. (Step 4.a)

Standard: Candidate determines that the reactor is at 100% RTP and is critical.

Examiners Cue:

Comment:

201 1-2 NRCJPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 10 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 9 Verify Reactor TRIPPED (Step 4.b)

Standard: Candidate trips the reactor by depressing either of the 2 reactor trip pushbuttons on the RTGB.

Examiners Note: Candidate will state the actions that the reactor has been tripped; Reactor trip and bypass breakers open, All IRPI indicate that rods are on the bottom, All rod bottom lights are illuminated, Neutron flux is lowering, Reactor is tripped.

Comment:

• Performance Step: 10 Stop ALL affected RCPs (Step 4.c)

Standard: Candidate will stop all of the RCPs by placing the RTGB control switches in the STOP position and observing the GREEN OFF indication for the RCP breakers.

Examiners Note:

Comment:

2011-2 NRC JPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 10 Form ES-C-i PERFORMANCE INFORMATION Performance Step: II Go To PATH-i while continuing with this procedure. (Step 4.d)

Standard: Candidate informs CRS to enter PATH-i while he continues in AOP-014.

Examiners Cue: Acknowledge as the CRS that you and the BOP will continue in PATH-I and the RO will continue in AOP-014.

Comment:

END OF TASK Terminating Cue: All RCPs have been secured and task is completed.

STOP TIME:

201 1-2 NRCJPM H NUREG 102i, Revision 9, Supplement 1

Appendix C Page 9 of 10 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM H Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

201 1-2 NRCJPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 10 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: Plant is at 100% RTP.

No equipment is out of service.

You are the Reactor Operator.

INITIATING CUE: Respond to plant events.

2011-2 NRC JPM H NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 10 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: Plant is at 100% RTP.

No equipment is out of service.

You are the Reactor Operator.

INITIATING CUE: Respond to plant events.

201 1-2 NRC JPM H NUREG 1021, Revision 9, Supplement 1

CONTINUOUS USE H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 3 PART 5 ABNORNAL OPERATING PROCEDURE AOP- 014 COMPONENT COOLING WATER SYSTEM MALFUNCTION REVISION 30 Page 1 of 115

AOP-014, Revision 30 Summary of Changes (PRR 473133)

Section A Steps 5 & Changed Path-i to Path-i or EOP-E-0 in preparation 19 for EOP upgrade. (PRR 473133)

Step 70 Changed step to GP-006-1 or 2 (PRR 473409)

RNO 3 Section B Step 6d Changed Path-i to Path-i or EOP-E-0 in preparation for EOP upgrade. (PRR 473133)

Section C Step 4d Changed Path-i to Path-i or EOP-E-0 in preparation for EOP upgrade. (PRR 473133)

Section IJ Step 4d Changed Path-i to Path-i or EOP-E-0 in preparation for EOP upgrade. (PRR 473133)

AOP-014 Rev. 30 Page 2 of i15

Rev. 30 AOP- 014 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 3 of 115 Purpose and Entry Conditions (Page 1 of 1)

1. PURPOSE This procedure provides the instructions necessary to mitigate abnormal conditions associated with Component Cooling Water (CCW) or any reduction in cooling to components served by the CCW System. Instructions for mitigating leakage into and out of the CCW system are also provided.

NOTE This procedure assumes valid indications are present. This procedure should NOT be entered for transmitter failures.

2. ENTRY CONDITIONS

a. Any abnormal condition associated with the CCW System as indicated by:

Improper Surge Tank Level

. Low Flow

. High CCW Temperature Unacceptable System Leakage

b. From AOP-OO5, Radiation Monitoring System, following an alarm on radiation monitor R-17 a confirmed rise in COW Surge Tank level.

c. From APP-OO1 on a loss of CCW flow to the RCPs.

- END -

Rev. 30 AOP-014 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 4 of 115 STEP H INSTRUCTIONS I RESPONSE NOT OBTAINED I

1. Implement The EALs

2. Make PA Announcement For Procedure Entry NOTE

• A loss of inventory may be indicated by a report of leakage or lowering of surge tank level.

• CCW Pump discharge pressure less than 78 psig will cause an alarm.

• CCW low flow is defined as less than 2200 gal per pump

• CCW high temperature is defined as greater than 105°F or greater than 125°F if in Mode 3.

3. Go To Appropriate Section For Indicated Malfunction:

Loss Of CCW Inventory Go To Section A Rising CCW inventory R R-17 Alarming Go To Section B CCW Pump Discharge Pressure Low Go To Section C CCW System Low Flow High Temperature Go To Section D

Rev. 30 AOP-014 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 5 of 115 J STEP H INSTRUCTIONS RESPONSE NOT OBTAINED

4. Determine If CCW Parameters Are Normal:

a. Check RCS temperature - LESS a. Perform one of the following:

THAN 350°F

• IF CCW HX outlet temperature is greater than 105°F. THEN Go To Step 3.

OR

• IF CCW HX outlet temperature is less than 105°F, THEN Go To Step 4.c.

b. Check CCW HX outlet b. Go To Step 3.

temperature - LESS THAN 125°F

c. Check CCW HX outlet c. Go To Step 3.

temperature - STABLE OR DECREASING

d. Check APP-0O1-F5, COW PMP LU d. Go To Step 3.

PRESS - EXTINGUISHED

5. Refer To Technical Specifications For Applicable LCOs

• T.S. 3.4.17 - Chemical and Volume Control System (CVCS)

• T.S. 3.5.2 - ECCS - Operating

• T.S. 3.5.3 - ECCS - Shutdown

• T.S. 3.6.6 - Containment Spray and Cooling Systems

• T.S. 3.7.6 - Component Cooling Water (CCW) System

6. Return to Procedure And Step In Effect

- END -

Rev. 30 AOP-014 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 45 of 115 j STEP H INSTRUCTIONS SECTION D RESPONSE NOT OBTAINED CCW SYSTEM LOW FLOW OR HIGH TEMPERATURE (Page 1 of 7)

1. Monitor RCP Temperatures Using One Of The Following:

• ERFIS group display RCP LOG OR

• RCP temperature recorder.

TR- 448 MOTOR BEARING RCP A RCP B RCP C UPPER THRUST PT.2 TE-417A PT.9 TE-427A PT.16 TE-437A LOWER THRUST PT.3 TE-417B PT.lO TE-427B PT.17 TE-4373 UPPER GUIDE PT.4 TE-418A PT.11 TE-428A PT.18 TE-438A LOWER GUIDE PT.5 TE-419 PT.12 TE-429 PT.19 TE-439

2. Check APP-001-E1, RCP BRG COOL Verify the following CCW Valves WTR LO FLOW - EXTINGUISHED open:

• CC-716A, CCW TO RCP ISO

• CC-716B, CCW TO RCP ISO

• CC-73O. BRG OUTLET ISO IF CCW to the RCP(s) can NOT be restored, THEN Go To Step 4.

3. Check ANY RCP Motor Bearing IF any RCP Motor Bearing Temperature - GREATER THAN 200°F temperature exceeds 200°F, THEN perform Step 4 Co To Step 5

Rev. 30 AOP-014 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 46 of 115 STEP H INSTRUCTIONS I I RESPONSE NOT OBTAINED I SECTION P CCW SYSTEM LOW FLOW OR HIGH TEMPERATURE (Page 2 of 7)

4. Determine If Reactor Trip Is Required As Follows:

a. Check Reactor - CRITICAL a. Perform the following:

1) Verify Control Rods -

TRIPPED

2) Stop ALL Affected RCPs.

3) IF Control Rods were inserted on the trip, THEN perform the following:

a) IF RCS temperature is greater than fR equal to 350°F, THEN Go To Step 4.d.

b) iy RCS temperature is less than 350°F, TEEN Go To Step 5.

4) IF Control Rods were already inserted, THEN Go To Step 5.

b. Verify Reactor - TRIPPED

c. Stop ALL Affected RCPs

d. Co To Path-i OR EOP-E-O, Reactor Trip or Safety Injection, While Continuing With This Procedure

5. Check CCW HX OUTLET Temperature Go To Step 17

- GREATER THAN 105° F

Rev. 30 AOP-014 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 47 of 115 H STEP H INSTRUCTIONS SECTION 0 RESPONSE NOT OBTAINED I

CCW SYSTEM LOW FLOW OR HIGH TEMPERATURE (Page 3 of 7)

• • • • ********* *t*t*** **************************** ************* ******* *****t CAUTION If only one SW Prnnp is running, it is subject to runoul: until the following step is completed.

6. Check SW Header Pressure AND Transition To Steps Indicated By The Table Below:

SW PRESSURE CONDITION STEP LESS THAN 40 PSIG 7 GREAThR THAN 50 PSIG 8 BETWEEN 40 P510 AND 50 PSIG 11

7. Raise SW Pressure As Follows:

a. Start additional SW Pumps as a. i ALL available SW Pumps are necessary to obtain at least running at least 40 psig 40 psig SW Header pressure can NJ be obtained, THEN isolate SW to the Turbine Building by closing:

• V6-16C, SW TURB BLDG ISO OR

• V6-16A AND V6-l6B, SW TURE BLDG SUPPLY

b. Check SW Header pressure - b. Go To Step 11.

GREATER THAN SO PSIG

Rev. 30 AOP-014 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 48 of 115

-H STEP H INSTRUCTIONS I

SECTION D RESPONSE NOT OBTAINED I

CCW SYSTEM LOW FLOW OR HIGH TEMPERATURE (Page 4 of 7)

8. Reduce SW Pressure As Follows:

a. Check number of SW Pumps a. WHEN personnel are available, Running - GREATER THAN 2 THEN locally perform Attachment 10. Throttling CCW Heat Exchanger SW Valves, while continuing with this procedure.

Go To Step 11.

b. Stop 1 Pump

c. Check SW Header Pressure - c. Go To Step 8.e.

GREATER THAN 50 PSIG

d. Go To Step 8.a

e. Check SW Header pressure - e. WHEN personnel are available, GREATER THAN 40 PSIG THEN locally perform Attachment 10, Throttling CCW Heat Exchanger SW Valves.

while continuing with this procedure.

9. Check SW To Turbine Building Go To Step 11.

Status - ISOLATED

Rev. 30 AOP-0l4 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 49 of 115 H STEP H INSTRUCTIONS SECTION D RESPONSE NOT OBTAINED CCW SYSTEM LOW FLOW OR HIGH TEMPERATURE (Page 5 of 7)

10. Shutdown Secondary Systems As Follows:

a. Close all MSIVs AND MSIV BYPASS Valves

b. Break vacuum to the Condenser as follows:

1) Depress AND hold the THINK Button

2) Open VACUUM BREAKER VALVES:

• MS-70A

• MS-70B

3) WHEN Vacuum Breaker Valves are Open, THEN Release the THINK Button

c. Verify The Following Equipment - STOPPED:

• FWPUMPAANDB

• CONDPUMPAANDB

• HEATER DRAIN PUMP A AND B

• GOV FLUID PUMP A AND B

• VACUUM PUMP A AND B

Rev. 30 AOP-014 COMPONENT COOLING WATER SYSTEM MALFUNCTION Page 50 of 115 f STEP H INSTRUCTIONS SECTION B RESPONSE NOT OBTAINED CCW SYSTEM LOW FLOW OR HIGH TEMPERATURE (Page 6 of 7)

11. Reduce Heat Loads On The CCW System As Necessary To Maintain Temperature

a. Stop Waste Gas Compressor(s)

b. Secure excess letdown

c. Check RHR - IN CORE COOLING c. Go To Step lle.

MODE

d. Minimize RCS cooldown rate

e. Reduce number of Charging Pumps in service

f. Throttle CC-775. CC FROM SPENT FUEL PIT HX BUTTERFLY, to maintain SEP temperature between 115°F and 120°F (located East of Heat Exchanger 9 foot above floor) 12 Check CCW Temperature - Go To Step 14.

• LESS THAN 105°F AND

• STABLE OR LOWERING

13. Go To The MAIN BODY, Step 4, Of This Procedure

Rev. 30 AOP-014 COMPONENT COOLING WATER SYSTEM MALFuNCTION Page 51 of 115 STEP H INSTRUCTIONS I

SECTION 0 RESPONSE NOT OBTAINED CCW SYSTEM LOW FLOW OR HIGH TEMPERATURE (Page 7 of 7)

14. Check CCW Temperature Based On Go To the MAIN BODY, Step 4. of RCS Temperature - GREATER THAN this procedure.

LIMITS USING TABLE BELOW RCS TEMPERATURE CCW TEMPERATURE GREATER THAN 350°F 105°F LESS THAN 350°F 125°F

15. Check Plant Status - AT POWER Go To the MAIN BODY, Step 4, of this procedure.

16. Initiate An Operability Determination For Components Cooled By CCW

17. Check RCP B OR C - RUNNING Go To the MAIN BODY, Step 4, of this procedure.

18. Check RCP B - RUNNING Place PCV-455A, PZR SPRAY 444G.

Controller to MAN AJ adjust controller output to ZERO.

19. Check RCP C - RUNNING Perform the following:

a. Place PCV-455B, PZR SPRAY 444H, Controller to MAN AND adjust controller output to ZERO.

b. Maintain PZR level between 30% and 40% to provide adequate PZR spray.

20. Go To The MAIN BODY, Step 4, Of This Procedure

- END -

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01344100205 Task

Title:

Align Deepwell Pump D to supply JPM No.: 2011-2 NRC JPM I cooling water to CCW Heat Exchangers K/A

Reference:

076 A2.01 (3.5/3.7) 076 G2.1.30 (4.4/4.0)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: X Actual Performance:

Classroom Simulator Plant X READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

• Plant is in Mode 3 following a reactor trip from 100% RTP

• An attack on the RNP site has resulted in a loss of the Startup Transformer and the Intake Structure.

• EDG B tripped while starting.

• EPP-28, Loss of Ultimate Heat Sink, is in progress.

• MSIVs and MSIV Bypass valves have been closed.

• EPP-28, Attachment 6, Deepwell Cooling to one of the available EDGs, has been completed for EDG A.

Task Standard: Align Deepwell Pump D to supply cooling to Component Cooling Water Heat Exchangers.

Required Materials: EPP-28, Attachment 7 General

References:

EPP-28, Loss of Ultimate Heat Sink, Revision 10 2011-2 NRC JPM I NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Handouts: EPP-28, Attachment 7 Initiating Cue: The CRS has directed you to align Deepwell Pump D to supply the cooling water to the Component Cooling Water Heat Exchangers lAW EPP-28, Attachment 7.

Time Critical Task: NO Validation Time: 12 minutes 2Oii-2 NRC JPM I NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet SIMULATOR SETUP N/A 2011-2 NRC JPM I NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 15 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with a check mark)

START TIME:

CAUTION The calculated maximum time a CCW Heat Exchanger may operate without cooling to preclude adverse system effects is less than 60 minutes.

NOTE A locked valve key is required for steps below.

J Performance Step: I Establish Aux Building SW Drain path as follows: (Att.7, Step 1)

a. Unlock and close SW-23, SW RETURN FROM AUXILIARY BUILDING Standard: Candidate simulates unlocking and closing valve SW-23 by rotating the valve handwheel in the clockwise direction until the closed stop is reached and the position indicator is pointing to CLOSE position.

Examiners NOTE: SW-23 is a butterfly valve.

SW-23 As Found Position Locked Open Examiner s CUE: Valve SW-23 indicates closed.

Comment:

2011-2 NRC JPM I NUREG-1021, Revision 9, Supplement 1

Appendix C Page 5 of 15 Form ES-C-i PERFORMANCE INFORMATION J Performance Step: 2 Establish Aux Building SW Drain path as follows: (Att.7, Step 1)

b. Close SW-739, CCW HEAT EXCHANGER A RETURN Standard: Candidate simulates closing valve SW-739 by rotating the valve handwheel in the clockwise direction until the closed stop is reached and the position indicator is pointing to CLOSE position.

Examiners NOTE: SW-739 is a butterfly valve.

SW-739 As Found Position Throttled Open Examiners CUE: Valve SW-739 indicates closed.

Comment:

q Performance Step: 3 Establish Aux Building SW Drain path as follows: (Att.7, Step 1)

c. Close SW-740, CCW HEAT EXCHANGER B RETURN Standard: Candidate simulates closing valve SW-740 by rotating the valve handwheel in the clockwise direction until the closed stop is reached and the position indicator is pointing to CLOSE position.

Examiners NOTE: SW-740 is a butterfly valve.

SW-740 As Found Position Throttled Open Valve SW-740 indicates closed.

Examiners CUE:

Comment:

2011-2 NRC JPM I NUREG-i021, Revision 9, Supplement 1

Appendix C Page 6 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 4 Establish Aux Building SW Drain path as follows: (Att.7, Step 1)

d. Close the DIESEL SW RETURN valve for the in service EDG

. SW-88, DIESEL A RETURN Standard: Candidate determines that valve SW-88 is closed by attempting to rotate the valve handwheel in the clockwise direction.

Examiners NOTE:

SW-88 As Found Position Closed. Valve SW-88 was placed in the closed position during the performance of EPP-28, Attachment 6.

Examiners CUE: Valve SW-88 is closed.

Comment:

2011-2 NRC JPM I NUREG-1 021, Revision 9, Supplement 1

Appendix C Page 7 of 15 Form ES-C-i PERFORMANCE INFORMATION q Performance Step: 5 At the in-service EDG, throttle the EDG ALTERNATE COOLING RETURN valve 5.5 turns in the close direction (4 turns open)

(Aft. 7, Step 2)

• SW-968, EDG A ALTERNATE COOLING RETURN Standard: Candidate simulates closing valve SW-968 5.5 turns by rotating the valve handwheel in the clockwise direction 5.5 turns.

Examiners NOTE: SW-968 As Found Position Unlocked and Open. Valve SW-968 was opened fully during the performance of EPP-28, Attachment 6.

Examiners CUE: Report that valve SW-968 valve has been rotated in the clockwise position for 5.5 turns.

Comment:

2011-2 NRC JPM I NUREG-i 021, Revision 9, Supplement 1

Appendix C Page 8 of 15 Form ES-C-i PERFORMANCE INFORMATION q Performance Step: 6 Open bypass for the normal EDG cooling valve for the in service EDG: (Att. 7, Step 3)

• A EDG: SW-87, TCV-1660 BYPASS Standard: Candidate simulates opening valve SW-87 by rotating the valve handwheel in the counterclockwise direction until the valve comes to a hard stop and stem is extended.

Examiners NOTE: SW-87 As Found Position - Closed Examiners CUE: Report that valve SW-87 handwheel has come to a hard stop and the valve stem is extended.

Comment:

Performance Step: 7 Open the in-service DIESEL TEMP CONTROL VALVE outlet:

(Att. 7, Step 4)

• SW-86, TCV-1660 OUTLET (A EDG)

Standard: Candidate simulates opening valve SW-86 by rotating the valve handwheel in the counterclockwise direction and observing the stem rising from the operator until the valve no longer rotates in the counterclockwise direction and the stem is extended.

Examiners NOTE: SW-86 As Found Position Closed. Valve SW-86 was closed during the performance of EPP-28, Attachment 6.

Examiners CUE: Report that valve SW-86 handwheel has come to a hard stop and the valve stem is extended.

Comment:

201 1-2 NRC JPM I NUREG-1021, Revision 9, Supplement 1

Appendix C Page 9 of 15 Form ES-C-i PERFORMANCE INFORMATION J Performance Step: 8 Establish CCW HX Cooling as follows: (Att. 7, Step 5)

a. Open SW-268, CCW HEAT EXCHANGER A RETURN VENT.

b. Observe flow from the vent.

c. Close SW-268.

Standard: Candidate simulates opening valve SW-268 by rotating the valve handwheel in the cQunterclockwise direction and observing water flow from the valve. Once venting is complete, close valve SW-268 by rotating the valve handwheel in the clockwise direction until the valve comes to a hard stop and the water ceases to flow.

Examiners NOTE:

Examiners CUE: Report that water is flowing when valve SW-268 is open and the water has stopped flowing when the valve is closed.

Comment:

2011-2 NRC JPM I NUREG-i 021, Revision 9, Supplement 1

Appendix C Page 10 of 15 Form ES-C-i PERFORMANCE INFORMATION q Performance Step: 9 Establish CCW HX Cooling as follows: (Aft. 7, Step 5)

d. Open SW-257, CCW HEAT EXCHANGER B RETURN VENT.

e. Observe flow from the vent.

f. Close SW-257.

Standard: Candidate simulates opening valve SW-257 by rotating the valve handwheel in the counterclockwise direction and observing water flow from the valve. Once venting is complete, close valve SW-257 by rotating the valve handwheel in the clockwise direction until the valve comes to a hard stop and the water ceases to flow.

Examiners NOTE:

Examiners CUE: Report that water is flowing when valve SW-257 is open and the water has stopped flowing when the valve is closed.

Comment:

J Performance Step: 10 Establish CCW HX Cooling as follows: (Att. 7, Step 5)

g. Open EACH CCW HEAT EXCHANGER RETURN Valve 1 Turn:

• SW-739

• SW-740 Standard: Candidate simulates opening valves SW-739 and SW-740 by rotating the handwheel in the counterclockwise direction 1 turn each.

Examiners NOTE: SW-739 and SW-740 AS Found Position CLOSED. Valves were closed earlier in this attachment performance.

Examiners CUE: Valves SW-739 and SW-740 have been opened I turn each.

Comment:

2011-2 NRC JPM I NUREG-i021, Revision 9, Supplement 1

Appendix C Page 1 1 of 15 Form ES-C-i PERFORMANCE INFORMATION NOTE

• The next two steps are intended to maintain CCW temperature less than 125°F while at the same time maintaining less than 1325 gpm total flow from Deep Well Pump D. This flow rate can be observed by either maintaining SW pressure greater than 18 psig at the CCW Heat Exchanger OR reading the well water flow indicator located in the EDG Room (FE-11135 or FE-11136).

• Note that subsequent steps will cut in additional SW flow to several components (20 to 30 gpm), therefore some margin to 18 psig must be maintained.

q Performance Step: 11 Throttle SW-739 AND SW-740 in equal increments to maintain CCW temperature less than 125°F. (Att. 7, Step 6)

Standard: Candidate simulates throttling valves SW-739 and SW-740 open by rotating the valve handwheels in the counterclockwise direction and monitoring the CCW temperature.

Examiners NOTE: CCW temperature is NOT available in the CCW Room and the candidate will have to communicate with the Control Room for the temperature to be monitored.

Examiners CUE: Report that CCW temperature is 117°F and stable following the throttling of valves SW-739 and SW-740 open 3 turns each.

Comment:

2011-2 NRC JPM I NUREG-1 021, Revision 9, Supplement 1

Appendix C Page 12 of 15 Form ES-C-I PERFORMANCE INFORMATION q Performance Step: 12 Control SW pressure at the CCW Heat Exchanger as follows:

(Att. 7, Step 7)

a. Throttle SW-739 AND SW-740 in equal increments to maintain SW pressure greater than 18 psig.

Standard: Candidate simulates throttling valves SW-739 and 740 by rotating the valve handwheels in the clockwise direction and observing the pressure indication at PI-1619A and B rising.

Examiners NOTE: Flow element FE-11136 is located in EDG A Room on the east side of the diesel. The flow indicator is 0-150 inches water column range with a mark of 1325 GPM on the indicator for excessive flow.

SW pressure indicators P1-I 61 9A and B are located at the south end of the CCW HXs adjacent to valves SW-739 and 740.

Report that SW pressure is currently at 17 psig.

Examiners CUE:

Report SW pressure has risen to 20 psig once valves SW-739 and SW-740 have been throttled closed I turn each.

Comment:

Performance Step: 14 Inform the Control Room that CCW cooling has been established. (Att. 7, Step 8)

Standard: Candidate notifies the Control Room that EPP-28, Attachment 7 has been completed for establishing CCW cooling.

Examiners NOTE:

Examiners CUE: Respond as the Control Room that CCW cooling has been established.

Comment:

2011-2 NRC JPM I NUREG-1 021, Revision 9, Supplement 1

Appendix C Page 13 of 15 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: CCW cooling has been established lAW EPP-28, Attachment 7; Evaluation of this JPM is complete.

STOP TIME:

2011-2 NRC JPM I NUREG-1021, Revision 9, Supplement 1

Appendix C Page 14 of 15 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 20i1-2 NRC JPM I Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM I NUREG-102i, Revision 9, Supplement 1

Appendix C Page 15 of 15 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• Plant is in Mode 3 following a reactor trip from 100% RTP

• An attack on the RNP site has resulted in a loss of the Startup Transformer and the Intake Structure.

• EDG B tripped while starting.

• EPP-28, Loss of Ultimate Heat Sink, is in progress.

• MSIVs and MSIV Bypass valves have been closed.

• EPP-28, Attachment 6, Deepwell Cooling to one of the available EDGs, has been completed for EDG A.

INITIATING CUE: The CRS has directed you to align Deepwell Pump D to supply the cooling water to the Component Cooling Water Heat Exchangers lAW EPP-28, Attachment 7.

2011-2 NRC JPM I NUREG-1021, Revision 9, Supplement 1

Appendix C Page 15 of 15 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• Plant is in Mode 3 following a reactor trip from 100% RTP

• An attack on the RNP site has resulted in a loss of the Startup Transformer and the Intake Structure.

• EDG B tripped while starting.

• EPP-28, Loss of Ultimate Heat Sink, is in progress.

• MSIVs and MSIV Bypass valves have been closed.

• EPP-28, Attachment 6, Deepwell Cooling to one of the available EDGs, has been completed for EDG A.

INITIATING CUE: The CRS has directed you to align Deepwell Pump D to supply the cooling water to the Component Cooling Water Heat Exchangers lAW EPP-28, Attachment 7.

201 1-2 NRC JPM I NUREG-1021, Revision 9, Supplement 1

Rev. 10 EPP-28 LOSS OF ULTIMATE HEAT SINK Page 165 of 209 ATTACHMENT 7 ESTABLISHING CCW COOLING (Page 1 of 3)

CAUTION The calculated maximum time a CCA1 Heat Exchanger may operate without cooling to preclude adverse system effects is less than 60 minutes.

NOTE A locked valve key is required for steps below.

1. Establish Aux Building SW Drain Pathway As Follows:

a. Unlock and Close SW-23, SW RETURN FROM AUXILIARY BUILDING.

b. Close SW-739, CCW HEAT EXCHANGER A RETURN.

c. Clnse SW-740, CCW HEAT EXCHANGER B RETURN.

d. Close the DIESEL SW RETURN valve for the in service EDG:

• SW-88, DIESEL A RETURN OR

• SW-92, DIESEL H RETURN

2. At the in-service EDC, throttle the EDC ALTERNATE COOLINC RETURN valve 5.5 turns in the close direction (4 turns open):

• SW-966. EDG B ALTERNATE COOLING RETURN OR

• SW-968, EDG A ALTERNATE COOLING RETURN

Rev. 10 EPP-28 LOSS OF ULTIMATE HEAT SINK Page 166 of 209 ATTACHMENT 7 ESTABLISHING CCW COOLING (Page 2 of 3)

3. Open Bypass For The Normal EGG cooling valve for the in service EGG:

• A EDG: SW-87, TCV-1660 BYPASS OR

• B EGG: SW-91, TCV-1661 BYPASS

4. Open the in-service DIESEL TEMP CONTROL VALVE outlet:

• SW-90, TCV-1661 OUTLET (B EGG)

OR

• SW-86, TCV-l660 OUTLET (A EGG)

5. Establish CCW HX Cooling As Follows:

a. Open SW-268. CCW HEAT EXCHANGER A RETURN VENT.

h. Observe flow from the vent.

c. Close SW-268.

d. Open SW-257. CCW HEAT EXCHANGER B RETURN VENT.

e. Observe flow from Lhe vent.

f. Close SW257.

g. Open EACH CCW HEAT EXCHANGER RETURN Valve 1 Turn:

• SW-739

• SW-740

Rev. 10 EPP-28 LOSS OF ULTIMATE HEAT SINK Page 167 of 209 ATTACHMENT 7 ESTABLISHING CCW COOLING (Page 3 of 3)

NOTE

• The next two steps are intended to maintain CCW temperature less than 125°F while at the same time maintaining less than 1325 gpm total flow from Deep Well Pump 0. This flow rate cam be observed by either maintaining SW pressure greater than 18 psig at the CCW Heat Exchanger Q) reading the well water flow indicator located in the HOG Room (FE-lll3S or FE-1l136)

• Note that subsequent steps will cut in additonal SW flow to several components (20 to 30 gpm) therefore some margin to 18 psig must be maintained.

6. Throttle SW-739 AND SW-74O in equal increments to maintain CCW Temperature less than 125°F

7. Control SW pressure at the CCW Heat Exchanger as follows:

a. Throttle SW-739 ffl SW-740 in equal increments to maintain SW pressure greater than 18 psig.

8. Inform the Control Room that CCW cooling Has been established.

- END -

Appendix C Page 1 of 9 Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01000110805 Task

Title:

Startup of Dedicated Shutdown UPS JPM No.: 2011-2 NRC JPM J Inverter lAW OP-602 K/A

Reference:

062 G2. 1.20 4.6 / 4.6 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: X Actual Performance:

Classroom Simulator Plant X READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

• DS UPS has been removed from service for maintenance.

• Maintenance has been completed and the UPS is ready to be restored to service.

• OP-602, Section 8.1.4, Steps la, ib, Ic and id have been completed.

Task Standard: OP-602, Section 8.1.4 has been completed with the DS UPS in service.

Required Materials: OP-602, Revision 56.

General

References:

OP-602, Dedicated Shutdown System, Revision 56.

Initiating Cue: The CRS has directed you to restore the DS UPS to service lAW OP 602, Section 8.1.4, beginning at Step 8.1.4.2.

Time Critical Task: NO Validation Time: 6 minutes 2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

Appendix C Page 2 of 9 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk )

START TIME:

Performance Step: I Verify OPEN all breakers on DS UPS Inverter (Step 8.1.4.2.a)

- DC INPUT Breaker

- Inverter Output Breaker

- Sync Reference AC Input Breaker Standard: Candidate simulates verifying the DC Input Breaker, Inverter Output Breaker and Sync Reference AC Input Breaker are open by ensuring that the breaker operating handles are in the down position. obtains all of the required equipment specified in the step.

Examiners Cue: Inform the operator that all of the breakers are in the open position.

Comment:

Performance Step: 2 VERIFY the Manual Bypass Switch is in the Bypass to Load position (Step 8.i.4.2.b)

Standard: Candidate simulates verifying that the switch is in the BYPASS TO LOAD position (Operating handle positioned to the RIGHT)

Examiners Cue: Inform the operator that the Manual Bypass Switch is positioned to the BYPASS TO LOAD position.

Comment:

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 9 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 3 CLOSE DC Input Breaker (Step 8.i.4.2.c)

Standard: Candidate simulates closing the DC Input Breaker by placing the breaker operating handle in the up position.

Examiners Cue: Inform the operator that the DC Input Breaker is closed.

Comment:

• Performance Step: 4 CLOSE Sync Reference AC Input Breaker (Step 8.1 .4.2.d)

Standard: Candidate simulates closing the Sync Reference AC Input Breaker by placing the breaker operating handle in the up position.

Examiners Cue: Inform the operator that the Sync Reference AC Input Breaker is closed.

Comment:

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 9 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 5 WHEN greater than 30 seconds have elapsed after closing the DC Input Breaker, THEN CLOSE the Inverter Output Breaker (Step 8.12.4.2.e)

Standard: Candidate simulates closing the Inverter Output Breaker by placing the breaker operating handle in the up position.

Examiners Cue: Inform the operator that the Inverter Output Breaker is closed.

Comment:

Performance Step: 6 VERIFY In Sync light illuminated (green) (Step 8.1.4.2.f)

Standard: Candidate observes the GREEN In Sync light illuminated on the inverter.

Examiners Cue: Inform the candidate that the In Sync GREEN light is illuminated.

Comment:

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 9 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 7 TRANSFER Manual Bypass Switch to Normal Operation Position (Step 8.i.4.2.g)

Standard: Operator simulates placing the MANUAL BYPASS SWITCH to the NORMAL OPERATION position by rotating the switch to the LEFT position.

Examiners Cue: Inform the candidate that the MANUAL BYPASS SWITCH has been placed in the NORMAL OPERATION position.

Comment:

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement i

Appendix C Page 6 of 9 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 8 CHECK Inverter Supplying Load light illuminated (green) (Step 8.1 .4.2.h)

Standard: Candidate observes the GREEN Inverter Supplying Load light illuminated on the inverter.

Examiners Cue: Inform the candidate that the Inverter Supplying Load GREEN light is illuminated.

Comment:

Performance Step: 9 CHECK Bypass Source Supplying Load light extinguished (Step 8.1.4.2.i)

Standard: Candidate observes the AMBER Bypass Source Supplying Load light extinguished on the inverter.

Examiners Cue: Inform the candidate that the Bypass Source Supplying Load AMBER light is extinguished.

Comment:

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 9 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 10 PRESS Alarm Reset Pushbutton (Step 8.i.4.2.j)

Standard: Operator simulates depressing the ALARM RESET pushbutton (Si) on the inverter.

Examiners Cue: Inform the operator that the ALARM RESET pushbutton has been depressed and all alarms are extinguished.

Comment:

Performance Step: 11 CHECK Inverter AC Output Voltage 116 to 124 volts AC (Step 8.1.4.2.k)

Standard: Operator observes the INVERTER AC OUTPUT VOLT meter for the appropriate voltage.

Examiners Cue: Inform the operator that the INVERTER AC OUTPUT VOLT meter indicates 121 Volts AC.

Examiners Note:

Comment:

END OF TASK Termination Cue: DS UPS Inverter has been returned to service lAW OP-602.

STOP TIME:

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 9 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM J Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 9 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• DS UPS has been removed from service for maintenance.

• Maintenance has been completed and the UPS is ready to be restored to service.

• OP-602, Section 8.1.4, Steps la, ib, icand Id have been completed.

INITIATING CUE: The CRS has directed you to restore the DS UPS to service lAW OP-602, Section 8.1.4, beginning at Step 8.1.4.2.

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 9 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• DS UPS has been removed from service for maintenance.

• Maintenance has been completed and the UPS is ready to be restored to service.

• OP-602, Section 8.1.4, Steps la, ib, ic and Id have been completed.

INITIATING CUE: The CRS has directed you to restore the DS UPS to service lAW OP-602, Section 8.1.4, beginning at Step 8.1.4.2.

2011-2 NRC JPM J NUREG 1021, Revision 9, Supplement 1

CONTINUOUS USE Section 8.1.4 Page 1 of 2 INIT 8.1.4 Startup of DS Uninterruptible Power Supply (UPS) Inverter Initial Conditions NOrj)This section has been screened lAW PLP-037 criteria and determined to be not applicable to PLP-037.

a. This revision has been verified to be the j.

latest revision available.

Date

b. Power Panel 51 is energized.

c. CKT 2, 5 KVA Inverter, on DS Distribution Panel A CLOSED.

d. Power Supply A is in service.

2. Instructions

a. VERIFY OPEN all breakers on DS UPS Inverter.

DC Input Breaker OPEN lnverter Output Breaker OPEN Sync Reference AC Input Breaker OPEN

b. VERIFY the Manual Bypass Switch is in the Bypass to Load position.

c. CLOSE DC Input Breaker.

d. CLOSE Sync Reference AC Input Breaker.

OP-602 Rev. 56 Page39of118

Section 8.1.4 Page 2 of 2 8.1.4.2 (Continued) INIT

e. WHEN greater than 30 seconds have elapsed after closing the DC Input Breaker, THEN CLOSE the Inverter Output Breaker.

f. VERIFY In Sync light illuminated (green).

g. TRANSFER Manual Bypass Switch to Normal Operation Position.

h. CHECK lnverter Supplying Load light illuminated (green).

CHECK Bypass Source Supplying Load light extinguished.

j. PRESS Alarm Reset Pushbutton.

k. CHECK Inverter AC Output Voltage 116 to 124 volts AC.

Initials Name (Print) Date Performed Ey . M 4 7Zd%

Approved By:

Shift Manager Date OP-602 Rev. 56 Page 40 of 1 18

Appendix C Page 1 of 14 Form ES-C-i PERFORMANCE INFORMATION Facility: HB ROBINSON Task No.: 01000101905 Task

Title:

Respond to Control Room JPM No.: 2011-2 NRC JPM K Inaccessibility K/A

Reference:

068 AA1.06 4.1 /4.2 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: X Actual Performance:

Classroom Simulator Plant X START JPM AT THE INSIDE AUXILIARY OPERATORS OFFICE READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

• Control Room has been evacuated due to a fire in the Control Room kitchen.

• The Shift Manager has implemented AOP-004, Control Room Inaccessibility.

• Charging Pumps B and C are operating.

• You are the Balance of Plant Operator.

Task Standard: AOP-004, Attachment 1, is complete with PZR level being controlled with the band specified.

Required Materials: AOP-004, Revision 19.

General

References:

AOP-004, Revision 19.

Initiating Cue: The SM directs you to perform the local actions contained in AOP-004, Attachment 1 for the Auxiliary Building Operator.

Time Critical Task: NO Validation Time: 20 minutes 2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 2 of 14 Form ES-C-I PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk )

START TIME:

Performance Step: I Obtain the following equipment: (Step 1)

At the Old Fire Equipment Building:

-Two-way radio

-Flashlight

-Locked valve keys

-Locked high rad area key Standard: Candidate obtains all of the required equipment specified in the step.

Examiners Cue: Inform the operator that he has all of the specified equipment.

Comment:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 14 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 2 Verify all of the following breakers OPEN (Step 2)

- REACTOR TRIP BREAKER A

- REACTOR TRIP BREAKER B

- BYPASS BREAKER A

- BYPASS BREAKER B Standard: Candidate simulates depressing the trip button on the REACTOR TRIP and BYPASS BREAKERS A AND B and notes that GREEN OPEN flag appears in the breaker status window.

Examiners Cue: Inform the operator that the GREEN OPEN flag appears in the breaker status window.

Comment:

Performance Step: 3 Notify the SM/CRS that the reactor has been tripped. (Step 3)

Standard: Candidate notifies the SM/CRS that the reactor has been tripped.

Examiners Cue: Respond as the SM that you understand that the reactor has been tripped.

Comment:

NOTE If the Control Room was evacuated due to a fire, the ventilation system is de-energized to prevent increasing the amount of oxygen available to support combustion.

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 14 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 4 Check Control Room Status CONTROL ROOM EVACUATED DUE TO FIRE (Step 4)

Standard: Candidate determines that Control Room was evacuated due to a fire in the Control Room kitchen as stated in the initial conditions.

Examiners Cue: NONE Comment:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement I

Appendix C Page 5 of 14 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 5 Open the following breakers at MCC-16: (Step 5)

- CONTROL ROOM AIR CONDITIONER, HVA-1A (CMPT 2F)

- CONTROL ROOM AIR CLEANING UNIT, HVE-19A (CMPT 4H)

Standard: Operator locates the breakers for HVA-1A and HVE-i9A on MCC-16 and simulates opening the breakers by positioning the breaker handle to the down position and the loss of breaker indication.

Examiners Note: SAF-NGGC-2175, Attachment 2, Sheet 3 of 5 for Motor Control Centers (MCCS) (600V or less) specifies that operating breakers with the doors closed is a Hazard Category 0 and refers to Attachment 3.

Attachment 3, Hazard Category 0 requires 100% Untreated Natural Fabric Long sleeve shirt and pants along with undergarments made from natural fabric and Safety Glasses or Goggles.

If needed, PPE for electrical safety is located in a locker adjacent to the Inside Auxiliary Operators office area.

Examiners Cue: Breakers have been positioned to the down position and the RED and GREEN lights are extinguished.

If electrical safety PPE is requested, discussion of the PPE required and its location can satisfy the PPE requirements.

Comment:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement I

Appendix C Page 6 of 14 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 6 Open the following breakers at MCC-18: (Step 6)

- CONTROL ROOM AIR CONDITIONER, HVA-1B (CMPT 2F)

- CONTROL ROOM AIR CLEANING UNIT, HVE-19B (CMPT 4H)

Standard: Operator locates the breakers for HVA-1B and HVE-19B on MCC-18 and simulates opening the breakers by positioning the breaker handle to the down position and the loss of breaker indication.

Examiners Cue: Breakers have been positioned to the down position and the RED and GREEN lights are extinguished.

Comment:

• Performance Step: 7 Open breaker V1-8A, SDAFW PUMP STEAM ISOLATION, at MCC-5 (CMPT 16F) (Step 7)

Standard: Operator simulates opening the breaker for V1-8A on MCC-5 by moving the breaker handle in the down position and noting the loss of breaker indication.

Examiners Cue: Breaker has been positioned to the down position and the RED and GREEN lights are extinguished.

Comment:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 14 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 8 Open the following breakers at MCC-iO: (Step 8)

-V2-i4A, SDAFW PUMP TO SIG A (CMPT 3C)

-V2-16A, MDAFW PUMP HEADER DISCHARGE TO S/G A (NORMAL POWER) (CMPT 4C)

-V2-16B, MDAFW PUMP HEADER DISCHARGE TO S/G B (CM PT 4F)

-V2-14C, SDAFW PUMP DISCHARGE TO S/G C (CMPT 4M)

Standard: Operator simulates opening the breakers for V2-14A, V2-16A, V2-16B and V2-14C on MCC-1O by moving the breaker handles in the down position and noting the loss of breaker indication.

Examiners Cue: Breakers have been positioned to the down position and the RED and GREEN lights are extinguished.

Comment:

Performance Step: 9 Notify the SM/CRS that breakers for the following valves have been opened: (Step 9)

Vi-8A, V2-14A, V2-14C, V2-16A, V2-16B.

Standard: Operator notifies the SM that the breakers for valves V1-8A, V2-14A, V2-14C, V2-16A, and V2-16B have been opened.

Examiners Cue: Respond as the SM that you understand that the breakers have been opened.

Comment:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 14 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 10 Check with SM/CRS LCV-i 1 5C breaker OPEN (Step 10)

Standard: Operator notifies the SM and requests the status of the breaker for valve LCV-i i5C.

Examiners Cue: Respond as the SM that the breaker for LCV-115C has been reported as open.

Comment:

• Performance Step: 11 Open CVC-358, RWSTTO CHARGING PUMP SUCTION, in the Charging Pump Room. (Step 11)

Standard: Operator simulates opening valve CVC-358 by rotating the operating handle 90 degrees.

Examiners Cue: Inform the operator that the valve has been opened by rotating the valve operating handle 90 degrees.

Examiners Note: CVC-358 is located in the Charging Pump Room approximately 7 feet from floor level on the west side of Charging Pump B. Operator will probably need a ladder to reach the valve or can describe where a ladder can be obtained (CCW Pump Room).

Comment:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 14 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 12 Verify LCV-1 15C, VOLUME CONTROL TANK OUTLET in the Charging Pump Room CLOSED (Step 12)

Standard: Operator simulates closing valve LCV-115C by declutching the motor and rotating the valve handwheel in the clockwise direction until the valve handwheel no longer turns.

Examiners Cue: Inform the operator that the declutching lever has been engaged and the valve has been closed.

Examiners Note: Valve LCV-115C is located above the floor level of the Charging Pump Room on a platform between Charging Pumps B and C. Operator should be able to describe the operation of the valve from the floor level.

Comment:

NOTE Steps 13 through 20 are performed at the Charging Pump Room Control Panel or Local Control Panel for Charging Pumps on the South Wall of the Charging Pump Room unless otherwise noted.

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 14 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 13 Place the following transfer switches IN LOCAL. (Step 13)

- CHARGING PUMP A TRANSFER SW

- CHARGING PUMP B TRANSFER SW

- CHARGING PUMP C TRANSFER SW Standard: Operator simulates placing the Charging Pump LOCAL/REMOTE switches on the Charging Pump Room Control Panel to the LOCAL position by rotating the pistol grip switches.

Examiners Cue: Inform the operator that the Charging Pump LOCALIREMOTE switches has been placed in LOCAL.

Comment:

• Performance Step: 14 Verify only one Charging Pump RUNNING (Step 14)

Standard: Operator simulates operating the START / STOP pushbutton controls to ensure that only one Charging Pump is operating by observing the RED running indication on only one pump is illuminated. Diverse indications provided are the noise in the room and observation of the pump rotating.

Examiners Note: The candidate will have to stop one of the running charging pumps by depressing the STOP pushbutton and observing the GREEN stop light illuminated.

Examiners Cue: If asked, inform the operator that B and C Charging Pumps are operating prior to any simulated actions.

Comment:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page ii of 14 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 15 Check neutron flux NI-51 SOURCE RANGE indication LESS THAN 1E05 CPS (Step 15)

Standard: Operator observes the NI-51 indicator on the Charging Pump Room Control Panel to determine the present reading.

Examiners Cue: Inform the operator that NI-51 indicates 5E03 CPS.

Comment:

Performance Step: 16 Observe the NOTE prior to Step 18 and Go To Step

18. (Step 16)

Standard: Operator observes the NOTE and proceeds to Step 18.

Examiners Cue: NONE Comment:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 12 of 14 Form ES-C-i PERFORMANCE INFORMATION NOTE Starting duty limitations allow four Charging Pump starts per hour and require a minimum of five minutes between starts.

• Performance Step: 17 Control PZR level from the Charging Pump Room as follows:

(Step 18)

a. Place the selector switch for the running Charging Pump on the CHARGING PUMP SPEED CONTROLLER to MAN

b. Turn the Speed Control Knob counter-clockwise to lower Charging Pump speed to minimum

c. Check PZR level GREATER THAN 71%

d. Stop the running Charging Pump Standard: Operator simulates placing the Charging Pump Speed Controller to MAN by rotating the switch from AUTO to MAN.

Operator simulates rotating the speed control knob counter clockwise to lower the Charging Pump speed to minimum.

Operator observes PZR level indicator to obtain present reading.

Operator responds to reported PZR level by simulating stopping the running Charging Pump.

Examiners Cue: Inform the operator that the Charging Pump Speed Controller has been placed in MAN.

Inform the operator that the speed control knob has been rotated counter-clockwise and Charging Pump speed is at minimum.

Inform the operator that PZR level is at 75%.

Comment:

END OF TASK Termination: AOP-004, Attachment I actions have been performed to maintain RCS inventory within the prescribed control band.

STOP TIME:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 13 of 14 Form ES-C-I VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM K Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement I

Appendix C Page 14 of 14 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• Control Room has been evacuated due to a fire in the Control Room kitchen.

• The Shift Manager has implemented AOP-004, Control Room Inaccessibility.

• You are the Balance of Plant Operator.

INITIATING CUE: The SM directs you to perform the local actions contained in AOP-004, Attachment 1 for the Auxiliary Building Operator.

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Appendix C Page 14 of 14 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• Control Room has been evacuated due to a fire in the Control Room kitchen.

• The Shift Manager has implemented AOP-004, Control Room Inaccessibility.

• You are the Balance of Plant Operator.

INITIATING CUE: The SM directs you to perform the local actions contained in AOP-004, Attachment 1 for the Auxiliary Building Operator.

2011-2 NRC JPM K NUREG 1021, Revision 9, Supplement 1

Rev. 19 AOP-004 CONTROL ROOM INACCESSIBILITY Page 9 of 32 INSTRUCT IONS I I RESPONSE NOT OBTAINED CONTINUOUS USE ATTACHMENT 1 AUXILIARY BUILDING OPERATOR (Page 1 of 9)

1. Obtain The Following Equipment:

. At the Old Fire Equipment Building:

Two-way radio Flashlight

. Locked valve keys a Locked high rad area key

2. Verify All Of The Following Trip open he following MC Set Breakers - OPEN Output Breakers:

• REACTOR TRIP BREAKER A a. GENERATOR A CIRCUIT BREAKER

• REACTOR TRIP BREAKER B b. GENERATOR B CIRCUIT BREAKER

• BYPASS BREAKER A

• BYPASS BREAKER B

3. Notify The SM/CRS That The Reactor Has Been Tripped NOTE If the Control Room was evacuated due to a fire, the ventilation system is de-energized to prevent increasing the amount of oxygen available to support combustion.

4. Check Control Room Status - Go To Step 7 CONTROL ROOM EVACUATED DUE TO F IRE

Rev. 19 AOP-004 CONTROL ROOM INACCESSIBILITY Page 10 of 32 j STEP H INSTRUCTIONS CONTINUOUS USE RESPONSE NOT OBTAINED I

ATTACHMENT 1 AUXILIARY BUILDING OPERATOR (Page 2 of 9)

5. Open The Following Breakers At MCC16:

• CONTROL ROOM AIR CONDITIONER, HVA-1A (CMPT 2F)

• CONTROL ROOM AIR CLEANING UNIT, HVE-19A (CMPT 4H)

6. Open The Following Breakers At MCC18:

• CONTROL ROOM AIR CONDITIONER, HVA-1B (CMPT 2F)

• CONTROL ROOM AIR CLEANING UNIT, HVE-19B (CMPT 4H)

7. Open Breaker V1-8A, SDAFW PUMP STEAM ISOLATION, At MCC-5 (CMPT 16F)

8. Open The Following Breakers At MCC1O:

• V2-14A, SDAFW PUMP TO S/G A (CMPT 3C)

• V2-16A, MDAFW PUMP HEADER DISCHARGE TO S/G A (NORMAL POWER) (CMPT 4C)

• V2-16B. MDAFW PUMP HEADER DISCHARGE TO S/G B (CMPT 4F)

• V2-14C, SDAEW PUMP DISCHARGE TO S/G C (CMPT 4M)

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9. Notify The SM/CRS That Breakers For The Following Valves Have Been Opened:

• V1-8A

• V2-14A

• V2-14C

• V2-16A

• V2-16B

• 10. Check with SM/CRS LCV-115C Notify SM/CRS to inform you when Breaker - OPEN. LCV-115C breaker is Open.

WHEN LCV-115C breaker is open, THEN perform Steps 11 and 12.

Go To SLep 13.

11. Open CVC-358. RWST TO CHARGING PUMP SUCTION, In The Charging Pump Room.

12. Verify LCV-115C, VOLUME CONTROL TANK OUTLET In The Charging Pump Room - CLOSED

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NOTE Steps 13 through 20 are performed at the Charging Pump Room Control Panel or Local Control Panel for Charging Pumps on the South wall of the Charging Pump Room unless otherwise noted.

13. Place The Following Transfer Switches - IN LOCAL

• CHARGING PUMP A TRANSFER SW

• CHARGING PUMP B TRANSFER SW

• CHARGING PUMP C TRANSFER SW

14. Verify Only One Charging Pump -

RUNNING

15. Check Neutron Flux NI-51 SOURCE j 30 minutes have elapsed since RANGE Indication - LESS THAN the Reactor Trip Ai neutron iü5 CPS 5 cs.

flux is greater than i0 THEN Go To Step 17.

Observe the NOTE prior to Step 22 and Go To Step 22.

16. Observe The NOTE Prior To Step 18 and Go To Step 18

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17. Perform The Following To Raise The Quantity Of Borated Water In The RCS:

a. Place the selector switch on CHARGING PUMP SPEED CONTROLLER to MAN

b. Turn the Speed Control Knob clockwise to raise Charging Pump speed to maximum

c. Check PZR Level On LI-6O7D-l c. WHEN PZR Level is greater

- GREATER THAN 81% than 81%. THEN Go To Step 17.d.

Observe the NOTE prior to Step 22 and Go To SLep 22.

d. Stop the running Charging Pump

e. Go To Step 19

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NOTE Starting duty limitations allow four Charging Pump starts per hour and require a minimum of five minutes between starts.

• 18. Control PZR Level From The Charging Pump Room As Follows:

a. Place the selector switch for the running Charging Pump on CHARGING PUMP SPEED CONTROLLER -to MAN

b. Turn the Speed Control Knob counter-clockwise to lower Charging Pump speed to minimum

c. Check PZR level - GREATER c. WHEN PZR level is greater THAN 71% than 71%, THEN stop the running Charging Pump ANJI Go To Step 19.

Go To Step 21.

d. Stop -the running Charging Pump

• 19. Check PZR level - LESS THAN 24% WHEN PZR level lowers to less than 24%, THEN perform Step 20.

Go To Step 21.

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20. Raise PZR Level As Follows:

a. Place a different CHARGING PUMP SPEED CONTROLLER to MAN

b. Turn the Speed Control Knob for the Charging Pump counter-clockwise to lower speed to minimum

c. Start the Charging Pump

21. Notify The SM/CRS That PZR Level Is Being ConLrolled Becween 24%

And 71%

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NOTE If an additional operator is not available, the Auxiliary Building Operator is expected to periodically monitor PZR pressure in the Charging Pump Room operate PZR Heaters in the Rod Control Room.

• 22. Check PZR Pressure Indicated On Perform the following:

P1-607-El In The Charging Pump Room - BETWEEN 2200 PSIG AND a. Contact the SM/CRS and 2250 PSIG request an additional operator with a radio.

b. Station the additional operator in the Rod Control Room to operate FZR Backup Heaters AND establish radio contact.

c. Direct the operation of the PZR Backup Heaters as follows:

1) Place the LOCAL/REMOTE switches for the PZR Backup Group Heaters at their respective EMERG-CONTR-STA in the LDCAL position.

2) Operate the PZR Heaters using the START/STOP Pushbuttons.

d. WHEN the PZR pressure is being controlled between 2200 psig and 2250 psig, THEN perform Step 23.

23. Notify The SM/CRS That PZR Pressure Is Being Controlled Between 2200 PSIG And 2250 PSIG

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24. Go To Step 15

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