ML120480074

Initial Exam 2011-302 Draft Administrative JPMs

ML120480074
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Site:	Robinson
Issue date:	02/10/2012
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Appendix C Job Performance Measure o

Form ES-C-I Worksheet Facility: HB ROBINSON Task No.: 01002100402 Task

Title:

Perform the RCS Leakage Surveillance JPM No.: 2011-2 NRC JPM Procedure Admin RO Al-i K/A

Reference:

G2.i.7 (RO 4.4)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant Task Standard: Candidate calculates the Unidentified and Identified Leakage.

Required Materials: OST-051 Reactor Coolant System Leakage Evaluation Station Curve 8.10, RCDT Level Calculator General

References:

OST-051 Reactor Coolant System Leakage Evaluation Station Curve 8.10, RCDT Level Handouts: OST-051 Reactor Coolant System Leakage Evaluation, Revision 45 marked up to the step for verifying current RCS temperature is equal to initial RCS temperature (Step 8.1.7.1). Attachment 10.1 must be marked with the initial parameter values and Attachment 10.5 marked with collected data.

Time Critical Task: NO Validation Time: 15 minutes 2011-2 NRC Admin JPM ROA1-1 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Initial Conditions: Plant is at 50% RTP.

You are the Reactor Operator.

Initiating Cue: The previous shift started OST-051, Reactor Coolant System Leakage Evaluation. The plant has remained at steady state, with NO automatic make-ups for ONE (1) hour.

Complete the provided procedure.

These final parameter values were recorded 60 minutes after the procedure was started except as noted for PRT and RCDT levels:

• RCS Temperature: 560°F

• VCT Level: 20.8 inches

• PZR Level: 36%

• PZR RELIEF TANK: 70.9% (24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> data)

• Accumulator A: 72%

• Accumulator B: 71%

• Accumulator C: 74%

• RCDT: 19% (12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> data)

• Charging Pump Leakoff Collection Tank: 32%

• Attachment 10.5, Components with Known Measured Leakage, has leakage on valve LCV-1 1 5B outlet flange that has been measured during the performance of OST-051 at 1000 ml in a 5 minute period.

2011-2 NRC Admin JPM ROA1-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 8 Form ES-C-I PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: i Candidate obtains copy of the marked up OST-051.

Standard: Candidate reviews the partially completed OST-051.

Examiners NOTE: Provide candidate with a copy of the marked up Procedure and Attachment.

Comment:

Performance Step: 2 WHEN at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> has elapsed, OR IF required by plant conditions to end this test, THEN perform the following: (Step 8.1.7.1,2,3).

1. Verify RCS temperature is equal to initial RCS temperature recorded on Attachment 10.1.

2. Record the Final Values for the parameters listed on Attachment 10.1.

3. Verify LCV-1 1 5A, VCT HLDP TK DIV, in the AUTO position.

Standard: RCS temperature is equal to the initial RCS temperature at the beginning of the OST.

Final values have been recorded on Attachment 10.1.

LCV-1 1 5A control switch has been placed in the AUTO position.

Examiners NOTE:

Examiners CUE LCV-115A has been placed in AUTO.

Corn ment:

2011-2 NRC Admin JPM RO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 8 Form ES-C-i PERFORMANCE INFORMATION Procedure NOTE: A decrease in VCT level represents plus (+) RCS leakage.

A decrease in Pressurizer level represents plus (+) RCS leakage.

Performance Step: 3 Calculate the Difference and Change in Volume for the parameters listed on Attachment 10.1 (Step 8.1.8).

Standard: Operator completes the Difference and Change in Volume calculations as directed on Attachment 10.1 (See KEY).

Examiners NOTE:

Comment:

Performance Step: 4 Perform a peer check of the calculated values listed in Attachment 10.1. (Step 8.1.9)

Standard: Candidate requests a peer check for the calculations performed.

Examiners NOTE:

Examiners CUE: State that a peer check has been performed.

Comment:

2011-2 NRC Admin JPM RO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 8 Form ES-C-i PERFORMANCE INFORMATION Procedure NOTE: A plus (+) calculated Total RCS Leakage Rate represents plus (+) RCS leakage.

Leak-rates (in gpm) on Attachment 10.2 should be rounded to two decimal places.

Performance Step: 5 On Attachment 10.2, Perform the following: (Step 8.1.10)

• Calculate the Total RCS Leakage Rate.

• Calculate the Identified RCS Leakage Rate.

• Calculate the Unidentified RCS Leakage Rate.

• Perform a peer check of the calculations performed on Attachment 10.2.

Standard: Candidate completes the Total, Identified and Unidentified leakage calculations as directed on Attachment 10.2 (See KEY).

Candidate requests a peer check of the calculations performed on Attachment 10.2.

Examiners NOTE:

Examiners CUE: Once the RO candidate has performed the Total, Identified and Unidentified RCS Leakage Rate calculations, inform them that they have completed the JPM task.

Comment:

END OF TASK 2011-2 NRC Admin JPM ROA1-1 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 8 Form ES-C-I PERFORMANCE INFORMATION Termination Cue: When the RCS leakage rate calculation is completed, the evaluation for this JPM is complete.

STOP TIME:________

2011-2 NRC Admin JPM ROA1-1 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 8 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC Admin JPM RO Al-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 Admin JPM RO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 8 Form ES-C-I JPM CUE SHEET INITIAL CONDITIONS:

Plant is at 50% RTP.

You are the Reactor Operator.

INITIATING CUE: The previous shift started OST-051, Reactor Coolant System Leakage Evaluation. The plant has remaine d at steady state, with NO automatic make-ups for ONE (1) hour.

Complete the provided procedure.

These final parameter values were recorde d 60 minutes after the procedure was started except as noted for PRT and RCDT levels:

• RCS Temperature: 560°F

• VCT Level: 20.8 inches

• PZR Level: 36%

• PZR RELIEF TANK: 70.9% (24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> data)

• Accumulator A: 72%

• Accumulator B: 71%

• Accumulator C: 74%

• RCDT: 19% (12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> data)

• Charging Pump Leakoff Collection Tank: 32%

• Attachment 10.5, Components with Known Measu red Leakage, has leakage on valve LCV-1 I 5B out let flange that has been measured during the performanc e of OST-051 at 1000 ml in a 5 minute period.

2011-2 NRC Admin JPM RD Al-I NUREG 1021, Revision 9, Supplement 1

C Progress EV Continuous Use ROBINSON NUCLEAR PLANT PLANT OPERATING MANUAL VOLUME 3 PART 9 OST-051 REACTOR COOLANT SYSTEM LEAKAGE EVALUATION (EVERY 72 HO URS DURING STEADY S TA TE OPERA TION AND WITHIN 12 HOURS AFTER REA CHING STEADY S TA TE OPERA TION)

REVISION 45 OST-051 Rev. 45 Page 1 of 24

SUMMARY

OF CHANGES PRR #00448048 OST-051, Revision 45 STEP REVISION COMMENTS 8.1.14.3 Added PERFORM Peer Check of data entry fields prior to uploading any data. PRR 00448048 Note prior to Deleted V:\Drive Link and added 8.1.14 N :\NGGWEB\RNP\Departments\Operations\RCS Leakage Program PRR 00450337 Attachment 10.4 Added There is a single valve outside of containment to obtain this note prior to sample in pipe alley WD-1731A, RCDT Discharge Header to WHUT 3.a.2.b Drain. PRR 00453076 0.4 Revised step to notify E&RC to obtain sample and analyze for 3.a.2.b activity and boron concentration lAW CP-003.

OST-051 Rev. 45 Page 2 of 24

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE .4

2.0 REFERENCES

5 3.0 RESPONSIBILITIES 6 4.0 PREREQUISITES 6 5.0 PRECAUTIONS AND LIMITATIONS 7 6.0 SPECIAL TOOLS AND EQUIPMENT 8 7.0 ACCEPTANCE CRITERIA 8 8.0 PROCEDURE 9 8.1 RCS Leakage Rate Test 9 9.0 RECORDS 14 10.0 ATTACHMENTS 14 10.1 LEAKAGE EVALUATION DATA SHEET 15 10.2 LEAKAGE EVALUATION CALCULATION SHEET 17 10.3 LEVEL TO GALLONS CONVERSION TABLE 18 10.4 ACTION LEVEL RESPONSE GUIDELINES 19 10.5 COMPONENTS WITH KNOWN MEASURED LEAKAGE 23 10.6 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM 24 OST-051 Rev. 45 Page 3 of 24

1.0 PURPOSE 1.1 To evaluate RCS leakage and to satisfy Improved Technical Specification Surveillance Requirement (ITS SR) 3.4.13.1.

1.2 This test is required when in Modes 1,2,3 or4. ITS SR 3.4.13.1 basis further defines the applicable conditions as within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching continuous steady state operation.

1.3 This test may be performed when in Mode 5 as long as the RCS is pressurized, there is a bubble in the Pressurizer and RCS/RHR temperature is constant.

However, a test under these conditions will not satisfy ITS SR 3.4.13.1.

1.4 This procedure supports the License Renewal Aging Management Program Boric Acid Corrosion Program by providing RCS leakage monitoring criteria (Reference 2.11).

OST-051 Rev. 45 Page 4 of 24

2.0 REFERENCES

2.1 Improved Technical Specifications [CO 3.4.13 and ITS 1.1 Definition of LEAKAGE 2.2 AP-030, NRC Reporting Requirements 2.3 EPCLA-01, Emergency Control 2.4 EGR-NGGC-0207, Boric Acid Corrosion Control (Generic Letter 88-05) 2.5 AOP-016, Excessive Primary Plant Leakage 2.6 OMM-015, Operations Surveillance Testing 2.7 ESR 94-471, Calculation for VCT Level vs. Volume 2.8 PLP-037, Conduct of Infrequently Performed Test or Evolutions and Pre-Job Briefs 2.9 CP-014, Primary-To-Secondary Leak Rate Calculation 2.10 SOER 97-1, Potential Loss of High Pressure Injection and Charging from Gas Intrusion (Credit taken for monitoring VCT level to address recommendation #1 of the SOER) 2.11 RNP-L/LR-0601, Aging Management Program, Boric Acid Corrosion Program 2.12 PWROG Letter, OG-07-286, Dated June 26. 2007 entitled Recommendations for Implementation of Guidelines for PWROG RCS Leak Rate Programs 2.13 PWROG Letter, OG-08-400 Dated November 19, 2008 entitled Clarification of the Recommendation of Guidelines for PWROG RCS Leakage Rate Program with Respect to NEI.-03-08 (PA-OSC-0189 and PA-OSC-0218) 2.14 WCAP-16423-NP, Pressurized Water Reactor Owners Group Standard Process and Methods for Calculating RCS Leak Rate for Pressurized Water Reactors 2.15 WCAP-16465-NP, Pressurized Water Reactor Owners Group Standard RCS Leakage Action Levels and Response Guidelines OST-051 Rev. 45 Page 5 of 24

3.0 RESPONSIBILITIES 3.1 Operations is responsible for:

3.1.1 Performance, review, and approval of this test.

3.1.2 Updating of the RCS Leakage Monitoring Spreadsheet after each performance of the surveillance.

3.2 Engineering is responsible for:

3.2.1 Development and maintenance of the RCS Leakage Monitoring Spreadsheet.

3.2.2 Establishment and updating of baseline mean (p) and standard deviation (a) values.

4.0 PREREQUISITES 4.1 This revision has been verified to be the latest revision available.

4.2 The Shift Manager has given permission to conduct this test.

4.3 RCS temperature is stable.

4.4 There is a bubble in the Pressurizer NOTE: ITS SR 3.4.13.1 requires performance of this test within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching steady state operating conditions in Modes 1, 2, 3, or 4. This test may be performed when stable in Mode 5 but only for tracking and trending purposes, not to satisfy the ITS SR requirements.

4.5 RCS pressure is stable.

4.6 Record RCS pressure. Z3psig <2J1 4.7 Record Plant Mode. Mode

(

OST-051 Rev. 45 Page 6 of 24

5.0 PRECAUTIONS AND LIMITATIONS 5.1 The accuracy of the RCS Leakage Rate Test is greatly improved when RCS temperature and Pressurizer level remain constant for the duration of the test.

5.2 This procedure should not be started unless the VCT level is high enough to avoid an automatic makeup during the performance of the RCS Leakage Rate Test.

5.3 Any steps not applicable shall be marked N/A and the reason(s) for any N/A noted in the Comments section of Attachment 10.6.

5.4 The principles of ALARA shall be used in planning and performing work and operations in the Radiation Control Area.

5.5 This procedure has been screened lAW PLP-037 criteria and determined to be outside the bounds of an Infrequently Performed Test or Evolution.

5.6 IF RCS pressure boundary LEAKAGE is verified, THEN the reactor shall be placed in Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in Mode 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> of discovery of pressure boundary leakage. Pressure boundary LEAKAGE is leakage (except SG leakage) through a non-isolable fault in an RCS component body, pipe wall, or vessel wall. (ITS LCO 3.4.13) 5.7 For the purpose of this procedure, IDENTIFIED RCS Leakage is leakage collected in either the PRT, the RCDT, a Safety Injection Accumulator, or the Charging pump Seal Leak-off Collection Tank. This type of RCS leakage is through seat leakage, NOT through wall OR RCS Pressure Boundary (RCPB) leakage. This type leakage is NOT to be confused with Miscellaneous Identified RCS Leakage as it may be related to interconnected systems outside the RCS Pressure Boundary (See P&L 5.13).

5.8 Whenever possible, use the ERFIS Computer for data collection. This will improve accuracy and reduce the potential for human error.

5.9 The ERFIS on-screen historic information may be used to assist with data collection. This is especially helpful during xenon transients or when in AOP-016, Excessive Primary Plant Leakage.

5.10 To improve the accuracy of the Pressurizer Relief Tank (PRT) level changes calculated during this procedure, a long term trend should be used for data collected from ERFIS. Duration of the long term PRT trend should be any period of stable PRT operation up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Due to possible evolutions affecting the PRT, the duration of the trend will be decided by the operator performing this test.

OST-051 Rev. 45 Page 7 of 24

5.11 IF R-ii is increasing and cannot be attributed to any specific leak location based on search results with the unit on line, THEN a task should be added to the forced outage schedule to inspect normally inaccessible areas for indication of leakage to the maximum extent practical.

5.12 To improve the accuracy of the Reactor Coolant Drain Tank (RCDT) level changes calculated during this procedure, a long term trend should be used for data collected from LI-i 003. Duration of the long term RCDT trend should be any period of stable RCDT operation up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Due to possible evolutions affecting the RCDT, the duration of long term trend will be determined by the SM/CRS.

5.13 Component leakage (valve packing, pump seal, fitting leakage, etc.) from accessible sources may only be treated as Miscellaneous Identified leakage if the source has been identified AND the actual value of the leakage is obtained by a measurement taken at the start or during the data taking interval for the surveillance test. The leakage must be measured each time the OST is performed if it is to be credited towards Miscellaneous Identified RCS Leakage.

Each component leak must have an active Work Order.

5.14 This procedure has been reviewed and found to be not applicable as per the requirements of OPS-NGGC-1 306, Reactivity Management.

6.0 SPECIAL TOOLS AND EQUIPMENT 6.1 Calibrated Stop Watch (If needed to collect Miscellaneous RCS Identified Leakage) 6.2 Graduated Container (If needed to collect Miscellaneous RCS Identified Leakage) 7.0 ACCEPTANCE CRITERIA 7.1 This test is acceptable if:

- Unidentified RCS Leakage Rate does NOT exceed i gpm

- Identified RCS Leakage Rate does NOT exceed 10 gpm

- Primary-to-Secondary leakage does NOT exceed 75 gpd through any one steam generator as determined by CP-014.

7.2 The reviewing and approving authorities may accept this test in accordance with provisions set forth in OMM-015, Operations Surveillance Testing.

OST-051 Rev. 45 Page 8 of 24

Section 8.1 Page 1 of 5 8.0 PROCEDURE INIT 8.1 RCS Leaka9e Rate Test 8.1.1 VERIFY RCS MAKEUP MODE in the AUTO position.

8.1.2 VERIFY RCS MAKEUP SYSTEM is ON.

8.1.3 IF desired, THEN PLACE LCV-115A, VCT/HLDP TK Dlv, in the VCT position. S/A NOTES: Whenever possible, use the ERFIS computer for data collection. This will improve accuracy and reduce the potential for human error.

The ERFIS on-screen historic information may be used to assist with data collection. This is especially helpful during a xenon transient or when in AOP-016, Excessive Primary Plant Leakage.

Measurement of leakage in Step 8.1.4.c, and the calculation of Total Measured Leakage in Step 8.1.4.d may be performed immediately prior to or at any time during the duration of this test.

The following step may be N/A if there is no active leakage issuing from components previously identified by work order.

8.1.4 IF there are any components that have known, active leakage, where the source is identified and can be treated as Miscellaneous Identified RCS Leakage or Known Non-RCPB Leakage per P&L 5.7 and P&L 5.13, THEN PERFORM the following on Attachment 10.5:

a. LIST the actively leaking component(s)

b. RECORD the Work Order number(s) for the component(s)

c. RECORD the measured leakage for the component(s)

d. CALCULATE the Total Measured Leakage Peer Check 8.1.5 RECORD the Initial Values for the parameters listed on Attachment 10.1.

OST-051 Rev. 45 Page 9 of 24

Section 8.1 Page 2 of 5 INIT 8.1.6 IF an automatic makeup occurs, THEN PERFORM the following:

1 VERIFY LCV-1 1 5A, VCT/HLDP TK Dlv, in the AUTO position.

2. STOP this procedure AND NOTE reason in Comments section.

NOTES: When this procedure is being performed to satisfy ITS SR 3.4.13.1, the preferred duration is greater than or equal to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and the minimum duration 15 minutes.

When this procedure is being performed as directed by an AOP, there is not a minimum duration requirement.

8.1.7 WHEN at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> has elapsed, OR, IF required by Plant conditions to end this test, THEN PERFORM the following:

1. VERIFY RCS temperature is equal to initial RCS temperature recorded on Attachment 10.1.

2. RECORD the Final Values for the parameters listed on Attachment 10.1.

3. VERIFY LCV-1 15A, VCT!HLDP TK DIV, in the AUTO position.

NOTES: A decrease in VCT level represents plus (+) RCS leakage.

A decrease in Pressurizer level represents plus (+) RCS leakage.

8.1.8 CALCULATE the Difference and Change in Volume for the parameters listed on Attachment 10.1.

8.1.9 PERFORM a peer check of the calculated values listed in Attachment 10.1.

OST-051 Rev. 45 Page 10 of 24

Section 8.1 Page 3 of 5 INIT NOTES: A plus (+) calculated Total RCS Leakage Rate represents plus (+) RCS leakage.

Leak-rates (in gpm) on Attachment 10.2 should be rounded to two decimal places.

8.1.10 On Attachment 10.2, PERFORM the following:

1. CALCULATE the Total RCS Leakage Rate.

2. CALCULATE the Identified RCS Leakage Rate.

3. CALCULATE the Unidentified RCS Leakage Rate.

4. PERFORM a peer check of the calculations performed on Attachment 10.2 8.1.11 IF unidentified RCS leakage is greater than 1.0 gpm OR the identified RCS leakage is greater than 10 gpm, THEN PERFORM the following:

1. CONSULT ITS LCO 3.4.13 for required actions.

2. CONSULT AP-030 for reporting requirements.

3. CONSULT EPCLA-01 for emergency action levels.

4. CONSULT AOP-016 for required actions.

8.1.12 IF RCS unidentified leakage is 0.05 gpm AND any valid R-24 monitor alarm OR any R-19 monitor indicates an increasing trend, THEN contact E&C Technician to perform Primary to Secondary Leakage Calculation for each steam generator in accordance with CP-014. (ITS LCO 3.4.13.d)

Primary to Secondary Leakage__________ gpd OST-051 Rev. 45 Page 11 of 24

Section 8.1 Page 4 of 5 IN IT 8.1.13 IF unidentified RCS leakage is equal to or greater than 0.03 gpm for 3 consecutive leak rate calculations, THEN perform the following:

1. Start an investigation immediately and inform plant staff.

2. IF not currently in progress, THEN start daily leak rate calculations.

NOTE: The RCS Leakage Monitoring Spreadsheet can be located at N:\NGGWEB\RN P\Departments\Operations\RCS Leakage Program or accessed from the OPS Tool Database 8.1.14 Update the RCS Leakage Monitoring Spreadsheet as follows:

1. LOG date and time.

2. ENTER RCS Identified and Unidentified RCS leakage.

3. PERFORM Peer Check of data entry fields prior to uploading any data.

4. CLICK UPLOAD DATA.

8.1.15 RECORD the following Unidentified Leak Rate data from the RCS Leakage Monitoring Spreadsheet:

1. Current Mean (p) value

2. Current Sigma (a) value

3. Current [p + 2a] value

4. Current [p + 3o] value

5. 7 Day Rolling Average

6. Number of Consecutive Days greater than (p)

7. Last 3 Daily Unidentified Leak Rates OST-051 Rev. 45 Page 12 of 24

Section 8.1 Page 5 of 5 INIT 8.1.16 Evaluate Unidentified Leakage against the Action Level Criteria Below:

Action Action Level Action Level Limit Description Exceeded Level (Circle One) 7-day rolling average of daily Unidentified RCS Tier One YES/NO leak_rates_is_greater_than_0.1_gpm Action Nine consecutive daily unidentified RCS leakage Level YES / NO values> mean (p)

Two consecutive daily Unidentified RCS leak Tier Two YES / NO rates_are_greater_than_0.15_gpm Action Two of three consecutive daily Unidentified leak Level YES / NO rates_greater_than_[p+

a 2 ]

One daily Unidentified RCS leak rate is greater Tier Three YES / NO than 0.3 gpm Action One daily Unidentified RCS leak rate is greater Level YES / NO than [p+3oj 8.1.17 IF any Unidentified RCS leakage Action Level (AL) is exceeded, THEN PERFORM the following:

1. REVIEW and implement the appropriate actions of Attachment 10.4, Action Level Response Guidelines while continuing with this procedure.

2. INITIATE an Action Plan lAW PLP-121 to document actions taken.

8.1.18 UPDATE leakage rate on Control Room status board.

8.1.19 IF Attachment 10.4, Action Level Response Guidelines was required, THEN ATTACH it to this OST when submitting to Records.

OST-051 Rev. 45 Page 13 of 24

INIT 9.0 RECORDS 9.1 Completed procedure, included completed partials shall be retained as a non permanent QA record 10.0 ATTACHMENTS 10.1 Leakage Evaluation Data Sheet 10.2 Leakage Evaluation Calculation Sheet 10.3 Level to Gallons Conversion Table 10.4 Action Level Response Guidelines 10.5 Components with Known Measured Leakage 10.6 Surveillance Test Procedure Certification and Review Form OST-051 Rev. 45 Page 14 of 24

0 0 ATTACHMENT 10.1 0

Page 1 of 2 LEAKAGE EVALUATION DATA SHEET REF ITEM VCT LVL PZR LVL RCS PZR ACCUM ACCUM ACCUM RCS STEP TEMP CHARGING TIME RELIEF A B C DRAIN PUMP LEAK 15 TANK (St .L 16 (5) (6) TANK OFF COLL.

or or (1) (7) 540F L9) [1-1003 TANK Ll-112 Ll-460 [1-470 or 8 or or (2) [10-200 Tavg [1-922 Ll-926 Ll-930 (3)

<540F TR-413 8.1.5 Initial Date/Time Date/Time Values in °F  %  %  %

ZLO 7 L 7

//

,, 71- 7 I i gal(1) gal(2) 8.1.7.2 gal(3)

Final Date/Time Date/Time Values in °F  %  %  %  %

gal(1) gal(2) gal(3) 8.1.8 Difference

(+1-) in  % gal  %  %  % gal Multiplier gal min(4) 23.99 50.56 7 gal/% 7 gal/% 7 gal/%

gal/in gal/%

8.1.8 Change in Volume (gals)

Comments OST-051 Rev. 45 Page 15 of 24

o o o ATTACHMENT 10.1 Page 2 of 2 (1) Use Curve Book, Curve 8.23 or Attachment 10.3, to convert PRT level into gallons OR mark as N/A if level did not increase.

(2) Use Curve Book, Curve 8.10, to convert RCDT level into gallons mark as N/A if level did not increase. To improve the accuracy of the Reactor Coolant Drain Tank (RCDT) level changes calculated during this procedure, a long term trend should be used for data collected from Ll-1003. A spreadsheet was developed to log RCDT levels that would provide a graph of the RCDT Trend. The file is located at V:\Operations\STA\RCDT Level. This graph or an ERFIS plot should be monitored for changes in inleakage rates into the RCDT. Duration of the long term RCDT trend should be any period of stable RCDT operation up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. (Actual duration of long term trend will be determined by the SM/CRS).

(3) Use Curve Book, Curve 8.22 or Attachment 10.3, to convert Charging Pump Leak-off Collection Tank level into gallons or mark as N/A if level did not increase.

(4) Minimum test duration of 15 minutes is required when performing this proced ure to satisfy ITS SR 3.4.13.1.

(5) Circle the respective indicator/indication used. IF ERFIS is in service, THEN use it to obtain values. IF ERFIS is not in service, THEN obtain the values from the respective RTGB indicators AND make a comment in the Comments section that RTGB indicators were used for the OST.

(6) An increase in SI Accumulator is (+) RCS Leakage. IF the increase is due to SI Accumulators sluicing from one accumulator to another, THEN do not include the change in the identified RCS leakage rate. A decrease in SI Accumulator is (-) RCS leakage ONLY IF RCS pressure is less than SI Accumulator pressure.

(7) PZR RELIEF TANK Level Initial & Final should be collect ed from ERFIS using long term trend up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of Stable PRT Operation. An ERFIS plot should be monitored for changes in inleakage rates into the PRT. Duration of the long term PRT trend should be any period of stable PRT operation up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. (Actual duratio n of long term trend will be determined by the SM/CRS)

OST-051 Rev. 45 Page 16 of 24

ATTACHMENT 10.2 Page 1 of 1 LEAKAGE EVALUATION CALCULATION SHEET Total RCS Leakage Rate VCT Volume Change gal Test Duration mm gpm PZR Volume Change gal Test Duration mm + gpm Total RCS Leakage Rate gpm Identified RCS Leakage Rate PRT Volume Change gal Test Duration mm gpm SI ACC A/B/C Volume Change gal Test Duration mm + gpm RCDT Volume Change gal Test Duration mm + gpm Leak-Off CoIl Tk Volume Change gal Test Duration mmn + gpm Miscellaneous ldentmfmed RCS Leakage Rate from Aft.

10.5 + gpm Total Identified RCS Leakage Rate (MSPI) gpm Unidentified RCS Leakage Rate Total RCS Leakage Rate gpm Total Identified RCS Leakage Rate

- gpm Unidentified RCS Leakage Rate gpm OST-051 Rev. 45 Page 17 of 24

ATTACHMENT 10.3 Page 1 of 1 LEVEL TO GALLONS CONVERSION TABLE Charging Pump Leakoff Pressurizer Relief Tank collection Tank Curve 8.22 Curve 8.23 Level Gallons Level Gallons Level Gallons Level Gallons Indicated Indicated Indicated Indicated L 0.17 51 22.00 70.0 7075.00 75.1 7572.25 2 0.33 52 22.66 70.1 7084.75 75.2 7582.00 3 0.50 53 2317 70.2 7094.50 75.3 7591.75 4 0.66 54 23.66 70.3 7104.25 75.4 7601.50 5 1.00 55 24.17 70.4 7114.00 75.5 7611.25 6 117 56 24.66 70.5 7123.75 75.6 7621.00 7 1.33 57 25.33 70.6 7133.50 75.7 7630.75 8 1,66 58 25.84 70.7 7143.25 75.8 7640.50 9 2.00 59 26.33 70.8 7153.00 75.9 7650.25 10 2.33 60 26.84 70.9 7162.75 76.0 7660.00 11 2.66 61 27.51 71,0 7172.50 76.1 7669.75 12 3.00 62 28.00 71.1 7182.25 76.2 7679.50

.i3 3.33 63 28.50 71.2 7192.00 76,3 7689.25

.i4 3.66 64 29.00 71.3 7201.75 76.4 7699.00

.i5 4.00 65 29.33 71.4 7211.50 76.5 7708.75 16 4.33 66 30.17 71.5 7221.25 76.6 7718.50 17 4.66 67 30.66 71.6 7231.00 76.7 7728.25 18 5.33 .68 31.17 71.7 7240.75 76.8 7738.00 19 5.56 69 31.66 71.8 7250.50 76.9 7747.75 20 6.00 70 32.17 71.9 7260,25 77.0 7757.50 21 6.50 71 32.66 72.0 7270.00 77.1 7767.25 22 7.00 72 33.33 72.1 7279.75 77.2 7777.00 23 7.33 73 33.66 72.2 7289.50 77,3 7786.75 24 7.84 74 34.33 72.3 7299.25 77.4 7796.50 25 8.33 75 34,66 72.4 7309.00 77.5 7806.25 26 8.83 76 35.17 72.5 7318.75 77.6 7816.00 27 9.33 77 35.66 72.6 7328.50 77.7 7825.75 28 9,84 78 36.00 72.7 7338.25 77.8 7835.50 29 10.33 79 36.50 72.8 7348.00 77.9 7845.25 30 10.83 80 36.84 72.9 7357.75 78.0 7855.00 31 11.33 81 37.33 73.0 7367.50 78,1 7864.75 32 11.84 82 37.66 73.1 7377.25 78.2 7874,50 33 12.33 83 38.00 73.2 7387.00 78,3 7884.25 34 13.00 84 38.50 73.3 7396.75 78.4 7894.00 35 13.49 85 38.83 73.4 7406.50 78.5 7903.75 36 14.00 86 39.17 73.5 7416.25 78.6 7913.50 37 14.66 87 39.66 73.6 7426.00 78.7 7923.25 38 15.18 88 40.00 73.7 7435.75 78.8 7933.00 39 15.66 89 40.33 73.8 7445.50 78.9 7942.75 40 16.17 90 40.50 73.9 7455.25 79.0 7952.50 41 16.66 91 40.84 74.0 7465.00 79.1 7962.25 42 17.00 92 41.00 74.1 7474.75 79.2 7972.00 43 17.66 93 41.33 74.2 7484.50 79.3 7981.75 44 18.33 94 41 66 74.3 7494.25 79.4 7991.50 45 18.83 95 41.83 74.4 7504.00 79.5 8001.25 46 19.33 96 41.84 74.5 7513.75 79.6 8011.00 47 20.00 97 42.33 74.6 7523.50 79.7 8020.75 48 20.50 98 42.66 74.7 7533.25 79.8 8030.50 49 21.00 99 42.83 74.8 7543.00 79.9 8040.25 50 21.50 100 43.00 74.9 7552.75 80.0 8050.00 75.0 7562.50 OST-051 Rev. 45 Page 18 of 24

ATTACHMENT 10.4 Page 1 of 4 ACTION LEVEL RESPONSE GUIDELINES DEFINITIONS: Daily means the daily average value which is the average of all valid measurements performed on a given calendar day.

MEAN (p) Average of the valid leak rates for a given period of time.

STANDARD DEVIATION (a) A measure of the degree of dispersion of the data from the mean value.

NOTE: Daily for below Action Levels should be interpreted as periodic if the ULR measurements are performed on less than a daily basis. That is, a periodic value is always a daily average value but is not evaluated every calendar day.

INIT Response Guidelines for Exceeding Tier One Action Levels

a. IF one 7-day rolling average of daily Unidentified RCS leak rates is greater than 0.1 gpm OR nine consecutive daily unidentified RCS leakage values> mean (p), THEN PERFORM the following:

1) CONFIRM indication.

2) PERFORM a confirmatory leak rate calculation.

3) CHECK for abnormal trends on other leakage indicators.

4) FORWARD data to Engineering to evaluate trends.

5) INCREASE monitoring as recommended by Engineering.

6) INITIATE a condition report. NCR #

7) NOTIFY Operations Management OST-051 Rev. 45 Page 19 of 24

ATTACHMENT 10.4 Page 2 of 4 ACTION LEVEL RESPONSE GUIDELINES INIT

2. Response Guidelines for Exceeding Tier Two Action Levels

a. IF two consecutive daily Unidentified RCS leak rates are greater than 0.15 gpm OR two of three consecutive daily Unidentified leak rates greater than [p+2aJ, THEN PERFORM the following:

1) VERIFY Tier One response guidelines have been performed.

2) COMMENCE a leak investigation as follows:

a) REVIEW recent plant evolutions.

.b) EVALUATE changes in other leakage detection indications.

.c) INITIATE walkdowns of various portions of potentially affected systems outside containment.

3) IDENTIFY the source of the increase in leakage as follows:

a) CHECK any components OR flow paths recently changed or placed in service, shutdown, vented, drained, or filled.

.b) CHECK any maintenance activity that may have resulted in increasing leakage.

.c) CHECK any filters recently alternated OR changed for leakage from their vents or drains.

INSPECT filter housing for gaskets leakage.

CHECK seal injection filters AND reactor coolant filter for signs of leakage.

4) NOTIFY Operations Management OST-051 Rev. 45 Page 20 of 24

ATTACHMENT 10.4 Page 3 of 4 ACTION LEVEL RESPONSE GUIDELINES INIT

3. Response Guidelines for Exceeding Tier Three Action Levels

a. IF one daily Unidentified RCS leak rate is greater than 0.3 gpm OR

[iJ+3o1 THEN PERFORM the following:

1) VERIFY Tier One AND Tier Two response guidelines have been performed.

2) IF increased leak rate is indicated inside containment, THEN PERFORM the following:

a) BEGIN PLANNING for a containment entry.

NOTE: There is a single valve outside of containment to obtain this sample in pipe alley WD-1731A.

.b) NOTIFY E&RC to OBTAIN a containment sump sample (during pump out) AND analyze for activity and boron concentration lAW CP-003, (looking for a larger than expected boric acid concentration OR other unexpected chemicals).

E&RC NOTIFIED

.c) EVALUATE other systems for indications of leakage.

.d) OBTAIN a containment atmosphere sample for indications of RCS leakage.

OST-051 Rev. 45 Page 21 of 24

ATTACHMENT 10.4 Page 4 of 4 ACTION LEVEL RESPONSE GUIDELINES INIT 3.0 (Continued) Response Guidelines for Exceeding Tier Three Action Levels

3) IDENTIFY the source of the leak.

4) QUANTIFY the leakage.

5) INITIATE a plan to repair the leak.

6) MONITOR containment airborne radiation levels AND area radiation monitors.

7) SAMPLE containment atmosphere for indications of RCS leakage.

8) MONITOR other containment parameters (temperature, pressure, humidity, etc.).

9) IF the leak source is found AND isolated OR stopped, THEN RE-PERFORM RCS leak rate calculation.

10) NOTIFY Operations Management OST-051 Rev. 45 Page 22 of 24

ATTACHMENT 10.5 Page 1 of 1 COMPONENTS WITH KNOWN MEASURED LEAKAGE NOTE: If leakage can NOT be collected in a suitable container to accurately measure in milliliters per minute (such as when leakage is in a high dose area but can be viewed by camera), this drops per minute conversion may be used. To convert drops per minute to gallons per minute, multiply drops per minute by 1.32 x 10-5 (0.0000132). The drop counting method shall only be allowed if NO other means is available to measure leakage due to inaccessibility from a radiation dose or personnel safety standpoint based on CRS/SM guidance.

To convert milliliters per minute to gallons per minute, multiply milliliters per minute by 2.64 x i0 (0.000264). This is the preferred method for calculating leakage.

Individual component leakage should not be rounded. Rounding should be completed in the Total Measured Leakage calculation to 2 significant digits, as this is what will be used by the Leak Rate program.

Measured Measured Duration Component Leakage Leakage Time Active Work (gpm) Volume Order Number

-// 1 t)rHe fl4/J. Z//- .XX.(A Total Measured Leakage gpm OST-051 Rev. 45 Page 23 of 24

ATTACHMENT 10.6 Page 1 of 1 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM Scheduled / Unscheduled (Circle one)

(If unscheduled, state reason for test and the page numbers included in partial test)

Test Performed By:

Initials Name (Print) Date Test Complete: Date:____________ Time:

Test Satisfactory: Yes I No (Circle one)

Reviewed by:

Shift Technical Advisor Date Comments: (Required if results were unsatisfactory)

Approved by:

Shift Manager Date OST-051 Rev. 45 Page 24 of 24

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REVISION 45 OST-051 Rev. 45 Page 1 of 24

SUMMARY

OF CHANGES PRR #00448048 OST-051, Revision 45 STEP REVISION COMMENTS 8.1.14.3 Added PERFORM Peer Check of data entry fields prior to uploading any data. PRR 00448048 Note prior to Deleted V:\Drive Link and added 8.1.14 N :\N GGWEB\RN P\Departments\Operations\RCS Leakage Program PRR 00450337 Attachment 10.4 Added There is a single valve outside of containment to obtain note prior to this sample in pipe alley WD-1731A, RCDT Discharge Header WHUT to 3.a.2.b Drain. PRR 00453076 Attachment 10.4 Revised step to notify E&RC to obtain sample and analyze for 3.a.2.b activity and boron concentration JAW CP-003.

f OST-051 Rev. 45 Page 2 of 24

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE

.4

2.0 REFERENCES

5 3.0 RESPONSIBILITIES 6

4.0 PREREQUISITES 6

5.0 PRECAUTIONS AND LIMITATIONS 7

6.0 SPECIAL TOOLS AND EQUIPMENT 8

7.0 ACCEPTANCE CRITERIA 8

8.0 PROCEDURE 9

8.1 RCS Leakage Rate Test 9

9.0 RECORDS 14 10.0 ATTACHMENTS 14 10.1 LEAKAGE EVALUATION DATA SHEET 15 10.2 LEAKAGE EVALUATION CALCULATION SHEET 17 10.3 LEVEL TO GALLONS CONVERSION TABLE 18 10.4 ACTION LEVEL RESPONSE GUIDELINES 19 10.5 COMPONENTS WITH KNOWN MEASURED LEAKAGE 23 10.6 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIE W

FORM 24 J OST-051 Rev. 45 Page 3 of 24

1.0 PURPOSE 1.1 To evaluate RCS leakage and to satisfy Improved Technical Specification Surveillance Requirement (ITS SR) 3.4.13.1.

1.2 This test is required when in Modes 1,2, 3 or4. ITS SR 3.4.13.1 basis further defines the applicable conditions as within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching continuous steady state operation.

1.3 This test may be performed when in Mode 5 as long as the RCS is pressurized, there is a bubble in the Pressurizer and RCS/RHR temperature is constant.

However, a test under these conditions will not satisfy ITS SR 3.4.13.1.

1.4 This procedure supports the License Renewal Aging Management Program Boric Acid Corrosion Program by providing RCS leakage monitoring criteria (Reference 2.11).

OST-051 Rev. 45 Page 4 of 24

2.0 REFERENCES

2.1 Improved Technical Specifications LCO 3.4.13 and ITS 1.1 Definition of LEAKAGE 2.2 AP-030, NRC Reporting Requirements 2.3 EPCLA-01, Emergency Control 2.4 EGR-NGGC-0207, Boric Acid Corrosion Control (Generic Letter 88-05) 2.5 AOP-016, Excessive Primary Plant Leakage 2.6 OMM-015, Operations Surveillance Testing 2.7 ESR 94-471, Calculation for VCT Level vs. Volume 2.8 PLP-037, Conduct of Infrequently Performed Test or Evolutions and Pre-Job Briefs 2.9 CP-014, Primary-To-Secondary Leak Rate Calculation 2.10 SOER 97-1, Potential Loss of High Pressure Injection and Charging from Gas Intrusion (Credit taken for monitoring VCT level to address recommendation #1 of the SOER) 2.11 RNP-LILR-0601, Aging Management Program, Boric Acid Corrosion Program 2.12 PWROG Letter, OG-07-286, Dated June 26, 2007 entitled Recommendations for Implementation of Guidelines for PWROG RCS Leak Rate Programs 2.13 PWROG Letter, OG-08-400 Dated November 19, 2008 entitled Clarification of the Recommendation of Guidelines for PWROG RCS Leakage Rate Program with Respect to NEI-03-08 (PA-OSC-0189 and PA-OSC-0218) 2.14 WCAP-1 6423-NP, Pressurized Water Reactor Owners Group Standard Process and Methods for Calculating RCS Leak Rate for Pressurized Water Reactors 2.15 WCAP-16465-NP, Pressurized Water Reactor Owners Group Standard RCS Leakage Action Levels and Response Guidelines J OST-051 Rev. 45 Page 5 of 24

3.0 RESPONSIBILITIES 3.1 Operations is responsible for:

3.1.1 Performance, review, and approval of this test.

3.1.2 Updating of the RCS Leakage Monitoring Spreadsheet after each performance of the surveillance.

3.2 Engineering is responsible for:

3.2.1 Development and maintenance of the RCS Leakage Monitoring Spreadsheet.

3.2.2 Establishment and updating of baseline mean (p) and standard deviation (a) values.

4.0 PREREQUISITES 4.1 This revision has been verified to be the latest revision available.

4.2 The Shift Manager has given permission to conduct this test.

4.3 RCS temperature is stable.

4.4 There is a bubble in the Pressurizer NOTE: ITS SR 3.4.13.1 requires performance of this test within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching steady state operating conditions in Modes 1, 2, 3, or 4. This test may be performed when stable in Mode 5 but only for tracking and trending purposes, not to satisfy the ITS SR requirements.

4.5 RCS pressure is stable.

4.6 Record RCS pressure. 223psig 4.7 Record Plant Mode. Mode OST-051 Rev. 45 Page 6 of 24

5.0 PRECAUTIONS AND LIMITATIONS 5.1 The accuracy of the RCS Leakage Rate Test is greatly improved when RCS temperature and Pressurizer level remain constant for the duration of the test.

5.2 This procedure should not be started unless the VCT level is high enough to avoid an automatic makeup during the performance of the RCS Leakage Rate Test.

5.3 Any steps not applicable shall be marked N/A and the reason(s) for any N/A noted in the Comments section of Attachment 10.6.

5.4 The principles of ALARA shall be used in planning and performing work and operations in the Radiation Control Area.

5.5 This procedure has been screened lAW PLP-037 criteria and determined to be outside the bounds of an Infrequently Performed Test or Evolution.

5.6 IF RCS pressure boundary LEAKAGE is verified, THEN the reactor shall be placed in Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in Mode 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> of discovery of pressure boundary leakage. Pressure boundary LEAKAGE is leakage (except SG leakage) through a non-isolable fault in an RCS component body, pipe wall, or vessel wall. (ITS LCO 3.4.13) 5.7 For the purpose of this procedure, IDENTIFIED RCS Leakage is leakage collected in either the PRT, the RCDT, a Safety Injection Accumulator, or the Charging pump Seal Leak-off Collection Tank. This type of RCS leakage is through seat leakage, NOT through wall OR RCS Pressure Boundary (RCPB) leakage. This type leakage is NOT to be confused with Miscellaneous Identified RCS Leakage as it may be related to interconnected systems outside the RCS Pressure Boundary (See P&L 5.13).

5.8 Whenever possible, use the ERFIS Computer for data collection. This will improve accuracy and reduce the potential for human error.

5.9 The ERFIS on-screen historic information may be used to assist with data collection. This is especially helpful during xenon transients or when in AOP-016, Excessive Primary Plant Leakage.

5.10 To improve the accuracy of the Pressurizer Relief Tank (PRT) level changes calculated during this procedure, a long term trend should be used for data collected from ERFIS. Duration of the long term PRT trend should be any period of stable PRT operation up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Due to possible evolutions affecting the PRT, the duration of the trend will be decided by the operator performing this test.

f OST-051 Rev. 45 Page 7 of 24

5.11 IF R-1 1 is increasing and cannot be attributed to any specific leak location based on search results with the unit on line, THEN a task should be added to the forced outage schedule to inspect normally inaccessible areas for indication of leakage to the maximum extent practical.

5.12 To improve the accuracy of the Reactor Coolant Drain Tank (RCDT) level changes calculated during this procedure, a long term trend should be used for data collected from LI-i 003. Duration of the long term RCDT trend should be any period of stable RCDT operation up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Due to possible evolutions affecting the RCDT, the duration of long term trend will be determined by the SM/CRS.

5.13 Component leakage (valve packing, pump seal, fitting leakage, etc.) from accessible sources may only be treated as Miscellaneous Identified leakage if the source has been identified AND the actual value of the leakage is obtained by a measurement taken at the start or during the data taking interval for the surveillance test. The leakage must be measured each time the OST is performed if it is to be credited towards Miscellaneous Identified RCS Leakage.

Each component leak must have an active Work Order.

5.14 This procedure has been reviewed and found to be not applicable as per the requirements of OPS-NGGC-1 306, Reactivity Management.

6.0 SPECIAL TOOLS AND EQUIPMENT 6.1 Calibrated Stop Watch (If needed to collect Miscellaneous RCS Identified Leakage) 6.2 Graduated Container (If needed to collect Miscellaneous RCS Identified Leakage) 7.0 ACCEPTANCE CRITERIA 7.1 This test is acceptable if:

- Unidentified RCS Leakage Rate does NOT exceed 1 gpm

- Identified RCS Leakage Rate does NOT exceed 10 gpm

- Primary-to-Secondary leakage does NOT exceed 75 gpd through any one steam generator as determined by CP-0i4.

7.2 The reviewing and approving authorities may accept this test in accordance with provisions set forth in OMM-015, Operations Surveillance Testing.

OST-051 Rev. 45 Page 8 of 24

Section 8.1 Page 1 of 5 8.0 PROCEDURE INIT 8.1 RCS Leakage Rate Test 8.1.1 VERIFY RCS MAKEUP MODE in the AUTO position.

8.1.2 VERIFY RCS MAKEUP SYSTEM is ON.

IF desired, THEN PLACE LCV-1 15A, VCT/HLDP TK Dlv, in the 8.1.3 VCT position. S/A NOTES: Whenever possible, use the ERFIS computer for data collection. This will improve accuracy and reduce the potential for human error.

The ERFIS on-screen historic information may be used to assist with data collection. This is especially helpful during a xenon transient or when in AOP-016, Excessive Primary Plant Leakage.

Measurement of leakage in Step 8.1.4.c, and the calculation of Total Measured Leakage in Step 8.1.4.d may be performed immediately prior to or at any time during the duration of this test.

The following step may be N/A if there is no active leakage issuing from components previously identified by work order.

8.1.4 IF there are any components that have known, active leakage, where the source is idenfified and can be treated as Miscellaneous Identified RCS Leakage or Known Non-RCPB Leakage per P&L 5.7 and P&L 5.13, THEN PERFORM the following on Attachment 10.5:

a. LIST the actively leaking component(s)

b. RECORD the Work Order number(s) for the component(s)

c. RECORD the measured leakage for the component(s)

d. CALCULATE the Total Measured Leakage Peer Check 8.1.5 RECORD the Initial Values for the parameters listed on Attachment 10.1.

Page 9 of 24

( OST-051 Rev. 45

Section 8.1 Page 2 of 5 IN IT 8.1.6 IF an automatic makeup occurs, THEN PERFORM the following:

1. VERIFY LCV-115A, VCT/HLDP TK Dlv, in the AUTO position.

2. STOP this procedure AND NOTE reason in Comments section.

NOTES: When this procedure is being performed to satisfy ITS SR 3.4.13.1, the preferred duration is greater than or equal to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and the minimum duration 15 minutes.

When this procedure is being performed as directed by an AOP, there is not a minimum duration requirement.

8.1.7 WHEN at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> has elapsed, OR, IF required by Plant conditions to end this test, THEN PERFORM the following:

1. VERIFY RCS temperature is equal to initial RCS temperature recorded on Attachment 10.1.

2. RECORD the Final Values for the parameters listed on Attachment 10.1.

3. VERIFY LCV-1 15A, VCT/HLDP TK DIV, in the AUTO position.

NOTES: A decrease in VCT level represents plus (+) RCS leakage.

A decrease in Pressurizer level represents plus (+) RCS leakage.

8.1.8 CALCULATE the Difference and Change in Volume for the parameters listed on Attachment 10.1.

8.1.9 PERFORM a peer check of the calculated values listed in Attachment 10.1.

OST-051 Rev. 45 Page 10 of 24

Section 8.1 Page 3 of 5 INIT NOTES: A plus (+) calculated Total RCS Leakage Rate represents plus (+) RCS leakage.

Leak-rates (in gpm) on Attachment 10.2 should be rounded to two decimal places.

8.1.10 On Attachment 10.2, PERFORM the following:

1. CALCULATE the Total RCS Leakage Rate.

2. CALCULATE the Identified RCS Leakage Rate.

3. CALCULATE the Unidentified RCS Leakage Rate.

4. PERFORM a peer check of the calculations performed on Attachment 10.2 8.1.11 IF unidentified RCS leakage is greater than 1.0 gpm OR the identified RCS leakage is greater than 10 gpm, THEN PERFORM the following:

1. CONSULT ITS LCO 3.4.13 for required actions.

2. CONSULT AP-030 for reporting requirements.

3. CONSULT EPCLA-01 for emergency action levels.

4. CONSULT AOP-016 for required actions.

8.1.12 IF RCS unidentified leakage is 0.05 gpm AND any valid R-24 monitor alarm OR any R-19 monitor indicates an increasing trend, THEN contact E&C Technician to perform Primary to Secondary Leakage Calculation for each steam generator in accordance with CP-014. (ITS LCO 3.4.13.d)

Primary to Secondary Leakage__________ gpd f OST-051 Rev. 45 Page 11 of 24

Section 8.1 Page 4 of 5 INIT 8.1.13 IF unidentified RCS leakage is equal to or greater than 0.03 gpm for 3 consecutive leak rate calculations, THEN perform the following:

1. Start an investigation immediately and inform plant staff.

2. IF not currently in progress, THEN start daily leak rate calculations.

NOTE: The RCS Leakage Monitoring Spreadsheet can be located at N:\NGGWEB\RNP\Departments\Operations\RCS Leakage Program or accessed from the OPS Tool Database 8.1.14 Update the RCS Leakage Monitoring Spreadsheet as follows:

1. LOG date and time.

2. ENTER RCS Identified and Unidentified RCS leakage.

3. PERFORM Peer Check of data entry fields prior to uploading any data.

4. CLICK UPLOAD DATA.

8.1.15 RECORD the following Unidentified Leak Rate data from the RCS Leakage Monitoring Spreadsheet:

1. Current Mean (p) value

2. Current Sigma (a) value

3. Current [p + 2a] value

4. Current [p + 3a] value

5. 7 Day Rolling Average

6. Number of Consecutive Days greater than (p)

7. Last 3 Daily Unidentified Leak Rates OST-051 Rev. 45 Page 12 of 24

Section 8.1 Page 5 of 5 INIT 8.1.16 Evaluate Unidentified Leakage against the Action Level Criteria Below:

Action Level Action Action Level Limit Description Exceeded Level (Circle One) 7-day rolling average of daily Unidentified RCS YES I NO Tier One leak_rates_is_greater_than_0.1_gpm Action Nine consecutive daily unidentified RCS leakage YES I NO Level values> mean (p)

Two consecutive daily Unidentified RCS leak YES / NO Tier Two rates are greater than 0.15 gpm Action Two of three consecutive daily Unidentified leak YES / NO Level rates greater than [p+2o]

One daily Unidentified RCS leak rate is greater YES / NO Tier Three than 0.3 gpm Action One daily Unidentified RCS leak rate is greater YES I NO Level than [p÷3o}

8.1.17 IF any Unidentified RCS leakage Action Level (AL) is exceeded, THEN PERFORM the following:

1. REVIEW and implement the appropriate actions of Attachment 10.4, Action Level Response Guidelines while continuing with this procedure.

2. INITIATE an Action Plan lAW PLP-121 to document actions taken.

8.1.18 UPDATE leakage rate on Control Room status board.

8.1.19 IF Attachment 10.4, Action Level Response Guidelines was required, THEN ATTACH it to this OST when submitting to Records.

OST-051 Rev.45 Page 13of24

INIT 9.0 RECORDS 9.1 Completed procedure, included completed partials shall be retained as a non permanent QA record 10.0 ATTACHMENTS 10.1 Leakage Evaluation Data Sheet 10.2 Leakage Evaluation Calculation Sheet 10.3 Level to Gallons Conversion Table 10.4 Action Level Response Guidelines 10.5 Components with Known Measured Leakage 10.6 Surveillance Test Procedure Certification and Review Form Page 14 of 24

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0 ATTACHMENT 10.1 Page 2 of 2 (1) Use Curve Book, Curve 8.23 or Attachment 10.3, to convert PRT level into gallons OR mark as N/A if level did not increase.

(2) Use Curve Book, Curve 8.10, to convert RCDT level into gallons Q mark as N/A if level did not increase. To improve the accuracy of the Reactor Coolant Drain Tank (RCDT) level changes calculated during this procedure, a long term trend should be used for data collected from LI-i 003. A spreadsheet was developed to log RCDT levels that would provide a graph of the RCDT Trend. The file is located at V:\Operations\STA\RCDT Level. This graph or an ERFIS plot should be monitored for changes in inleakage rates into the RCDT. Duration of the long term RCDT trend should be any period of stable RCDT operation up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. (Actual duration of long term trend wHI be determined by the SM/CRS).

(3) Use Curve Book, Curve 8.22 or Attachment 10.3, to convert Charging Pump Leak-off Collection Tank level into gallons or mark as N/A if level did not increase.

(4) Minimum test duration of 15 minutes is required when performing this procedure to satisfy ITS SR 3.4.13.1.

(5) Circle the respective indicator/indication used. IF ERFIS is in service, THEN use it to obtain values. IF ERFIS is not in service, THEN obtain the values from the respective RTGB indicators AND make a comment in the Comments section that RTGB indicators were used for the OST.

(6) An increase in SI Accumulator is (+) RCS Leakage. IF the increase is due to SI Accumulators sluicing from one accumulator to another, THEN do not include the change in the identified RCS leakage rate. A decrease in SI Accumulator is (-) RCS leakage ONLY IF RCS pressure is less than SI Accumulator pressure.

(7) PZR RELIEF TANK Level Initial & Final should be collected from ERRS using long term trend up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of Stable PRT Operation. An ERFIS plot should be monitored for changes in inleakage rates into the PRT. Duration of the long term PRT trend should be any period of stable PRT operation up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. (Actual duration of long term trend will be determined by the SM/CRS)

Rev. 45 Page 16 of 24 OST-051

ATTACHMENT 10.2 Page 1 of 1 LEAKAGE EVALUATION CALCULATION SHEET Total RCS Leakage Rate 1- Fit 17 VCT Volume Change /1, fhai J ci Test Duration mm gpm PZR Volume Change t g1 Test Duration mm + 0 gpm Total RCS Leakage Rate / 2? ggp Identified RCS Leakage Rate

/(1*

PRT Volume Change k.i Test Duration / ç/ 4-iiin I/f & gpj SI ACC NB/C Volume Change 0 gal Test Duration mm + (I gm RCDT Volume Change - -gal J) 1 Cl (J

Test Duration mm + 7 gpm Leak-Off CoIl Tk Volume Change 7 / gal Test Duration mm + t9t /g gpm Miscellaneous Identified RCS Leakage Rate from Aft. 10.5 + f 5

1 Total Identified RCS Leakage Rate (MSPI) Of 3 gpm Unidentified RCS Leakage Rate Total RCS Leakage Rate  :. / 2$m Total Identified RCS Leakage Rate -

- c .i rn

/. 7_1PfT1 Unidentified RCS Leakage Rate

\

\

f OST-051 Rev. 45 Page 17 of 24

ATTACHMENT 10.3 Page 1 of 1 LEVEL TO GALLONS CONVERSION TABLE Charging Pump Leakoff Pressurizer Relief Tank Collection Tank Curve 8.22 Curve 8.23 Level Gallons Level Gallons Level Gallons Level Gallons Indicated Indicated Indicated Indicated 0.17 51 22.00 70.0 1975.00 75.1 7572.25 1

0.33 52 2Z.55 70.1 7064.75 75.2 152.00 2

0.50 53 2111 70.2 7094.50 75.3 7591.75 3

0.66 54 23.66 70.3 7104.25 75.4 7601.50 4

1.00 55 24.17 70.4 7114.00 75.5 7611.25 5

1.17 56 24.66 70.5 7123.75 75.6 1921.00 6

1.33 57 25.33 70.6 7133.50 75.7 7630.75......_.

7 8 1.66 58 25.84 70.7 7143.25 75.8 2.00 59 26.31 70.8 7153.00 75.9 7650.25 9

2.33 60 26.84 70.9 7162.75 76.0 7660.00........

10 2.66 61 27.51 71.0 7172.50 76.1 7669.75..........

11 3.00 62 28.00 71.1 ,,Zj.52.25 76.2 1979.50 12 3.33 63 28.50 71.2 7192.00 76.3 7689.25...._..

13 3.66 64 29.00 71.3 7201.75 76.4 7699.00 14 4.00 65 29.33 71.4 7211.50 76.5 7708.75 15 4.33 66 30.17 71.5 7221.25 76.6 7718.50 16 4.66 67 30.66 71.6 7231.00 76.7 7728.25 17 31.17 71 7 124.0.75 76.8 7738.00 18 5.33 68 69 31.66 71.8 725050 76.9 7747.75 19 5.66 6.00 70 32.17 71.9 7260.25 77.0 7757.50 20 6.50 71 32.6 72.0 7270.00 77.1 7767.25 21 22 7.00 72 33.3.1 72.1 7279.75 77.2 1777.00 7.33 73 33.66 72.2 12.5.9.50 77.3 7786.75.......

23 7.84 74 34.33 72.3 7299.25 77.4 7796.50 24 8.33 75 34.66 72.4 7309.00 77.5 7806.25 25 8.83 76 35,17 72.5 7318.75 77.6 7816.00 26 77 35.6& 72.6 7328 50 77.7 7825.75 27 9.33 9.84 78 36.00 72.7 7338.25 77.8 7835.50 28 10.33 79 36.50 72.8 7348.00 77.9 7845.25 29 80 36.84 72.9 7357.75 78.0 7855.00 30 i.03.

31 11.33 81 37.31 73.0 7367.50 78.1 1964.75 11.84 82 37.66 73.1 7377.25 78.2 7874.50 32 83 38.00 73.2 7387.00 78.3 7884.25 33 12.11 84 38.50_ 73.3 7396.75 78.4 1994.00 34 13.00 13.49 85 38.83 73.4 7406.50 78.5 7903.7&........

35 36 14.00 86 39.17 73.5 14.1.6.25 78.6 1913.50 14.66_ 87 39.66 73.6 1425.00 78.7 1923.25 37 38 15.18 88 40.00 73.7 142.5.75 78.8 1933.00 15.66 89 40.33 73.8 7445.50 78.9 1942.75 39 16.17 90 40.50 73.9 1455.25 79.0 7952.50 40 16.66 91 40.84 74.0 7465.00 79.1 1962.25 41 17.00 92 41.00 74.1 7474.75 79.2 7972.00 42 17.66 93 41.33 74.2 j454.50 79.3 7981.75

.43 7991.50 44 94 4,1.65.. 74.3 7494.25 79.4 95 41.83 74.4 i54.00 79.5 8001.25 45 96 41.84.. 74.5 15+/-3.75 79.6 .,8Qjl.00 46 8020.75 47 20.00 97 42.33 74.6 7523,50 79.7 20.50 98 42.66 74.7 7533.25 79.8 8030.50 48 21.00 99 42..81 74.8 7543.00 79.9 ..8040.25 49 8050.00 50 21.50 100 43.00 74.9 1552.75 80.0 75.0 7562.50 OST-051 Rev. 45 Page 18 of 24

ATTACHMENT 10.4 Page 1 of4 ACTION LEVEL RESPONSE GUIDELINES DEFINITIONS: Daily means the daily average value which is the average of all valid measurements performed on a given calendar day.

MEAN (p) Average of the valid leak rates for a given period of time.

STANDARD DEVIATION (u) A measure of the degree of dispersion of the data from the mean value.

NOTE: Daily for below Action Levels should be interpreted as periodic if the ULR measurements are performed on less than a daily basis. That is, a periodic value is always a daily average value but is not evaluated every calendar day.

INIT Response Guidelines for Exceeding Tier One Action Levels

a. IF one 7-day rolling average of daily Unidentified RCS leak rates is greater than 0.1 gpm OR nine consecutive daily unidentified RCS leakage values> mean (p), THEN PERFORM the following:

1) CONFIRM indication.

2) PERFORM a confirmatory leak rate calculation.

3) CHECK for abnormal trends on other leakage indicators.

4) FORWARD data to Engineering to evaluate trends.

5) INCREASE monitoring as recommended by Engineering.

6) INITIATE a condition report. NCR #

7) NOTIFY Operations Management j OST-051 Rev. 45 Page 19 of 24

ATTACHMENT 10.4 Page 2 of 4 ACTION LEVEL RESPONSE GUIDELINES INIT

2. Response Guidelines for Exceeding Tier Two Action Levels

a. IF two consecutive daily Unidentified RCS leak rates are greater than 0.15 gpm OR two of three consecutive daily Unidentified leak rates greater than [p+2oJ, THEN PERFORM the following:

1) VERIFY Tier One response guidelines have been performed.

2) COMMENCE a leak investigation as follows:

.a) REVIEW recent plant evolutions.

.b) EVALUATE changes in other leakage detection indications.

.c) INITIATE walkd owns of various portions of potentially affected systems outside containment.

3) IDENTIFY the source of the increase in leakage as follows:

.a) CHECK any components OR flow paths recently changed or placed in service, shutdown, vented, drained, or filled.

.b) CHECK any maintenance activity that may have resulted in increasing leakage.

.c) CHECK any filters recently alternated OR changed for leakage from their vents or drains.

INSPECT filter housing for gaskets leakage.

CHECK seal injection filters AND reactor coolant filter for signs of leakage.

4) NOTIFY Operations Management OST-051 Rev. 45 Page 20 of 24

ATTACHMENT 10.4 Page 3 of 4 ACTION LEVEL RESPONSE GUIDELINES INIT

3. Response Guidelines for Exceeding Tier Three Action Levels

a. IF one daily Unidentified RCS leak rate is greater than 0.3 gpm OR

[p+3a], THEN PERFORM the following:

1) VERIFY Tier One AND Tier Two response guidelines have been performed.

2) IF increased leak rate is indicated inside containment, THEN PERFORM the following:

.a) BEGIN PLANNING for a containment entry.

NOTE: There is a single valve outside of containment to obtain this sample in pipe alley WD-1731A.

.b) NOTIFY E&RC to OBTAIN a containment sump sample (during pump out) AND analyze for activity and boron concentration lAW CP-003, (looking for a larger than expected boric acid concentration OR other unexpected chemicals).

E&RC NOTIFIED

.c) EVALUATE other systems for indications of leakage.

.d) OBTAIN a containment atmosphere sample for indications of RCS leakage.

J OST-051 Rev. 45 Page 21 of 24

ATTACHMENT 10.4 Page 4 of 4 ACTION LEVEL RESPONSE GUIDELINES INIT 3.0 (Continued) Response Guidelines for Exceeding Tier Three Action Levels

3) IDENTIFY the source of the leak.

4) QUANTIFY the leakage.

5) INITIATE a plan to repair the leak.

6) MONITOR containment airborne radiation levels AND area radiation monitors.

7) SAMPLE containment atmosphere for indications of RCS leakage.

8) MONITOR other containment parameters (temperature, pressure, humidity, etc.).

9) IF the leak source is found AND isolated OR stopped, THEN RE-PERFORM RCS leak rate calculation.

10) NOTIFY Operations Management OST-051 Rev. 45 Page 22 of 24

ATTACHMENT 10.5 Page 1 of 1 COMPONENTS WITH KNOWN MEASURED LEAKAGE NOTE: If leakage can NOT be collected in a suitable container to accurately measure in milliliters per minute (such as when leakage is in a high dose area but can be viewed by camera), this drops per minute conversion may be used. To convert drops per minute to gallons per minute, multiply drops per minute by 1.32 x 10-5 (0.0000132). The drop counting method shall only be allowed if NO other means is available to measure leakage due to inaccessibility from a radiation dose or personnel safety standpoint based on CRS/SM guidance.

To convert milliliters per minute to gallons per minute, multiply milliliters per minute by 2.64 x 10 (0.000264). This is the preferred method for calculating leakage.

Individual component leakage should not be rounded. Rounding should be completed in the Total Measured Leakage calculation to 2 significant digits, as this is what will be used by the Leak Rate program.

Meas u red Meas u red Duration Active Work Component Leakage Leakage Time Order Number (gpm) Volume i&V.-//i OW/

O,c /c&I, I.

,Jcl M/id. 2-oil- xx?cA i%Ja

-J Total Measured Leakage J 9, gpm Page 23 of 24 f OST-051 Rev. 45

ATTACHMENT 10.6 Page 1 of 1 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM ule Unscheduled (Circle one)

(If unscheduled state reason for test and the page numbers included in partial test)

Test Performed By:

,flarne7ynO Test Complete: Date: Time:_____________

Test Satisfactory: Yes I No (Circle one)

Reviewed by:

Shift Technical Advisor Date Comments: (Required if results were unsatisfactory)

Approved by:

Shift Manager Date J OST-051 I Rev. 45 I Page 24 of 24

Appendix C fto Job Performance Measure Form ES-C-I Worksheet Facility: HB ROBINSON Task No.: 01000100905 Task

Title:

Calculate the Boron Addition JPM No.: 2011-2 NRC JPM RD Required Prior to Initiating a Natural A1-2 Circulation Cooldown to CSD K/A

Reference:

G2.1.25 3.9/4.2 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator 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 Perform ance Measure will be satisfied.

Initial Conditions:

• The plant tripped from 50% RTP when a loss of off-site power occurred.

• The crew is performing EPP-5, Natural Circulation Cooldown.

• The TSC is NOT staffed.

• Core Burnup is 11000 MWD/MTU

• Boron Concentration is 600 PPM

• Tavg is 54TF

• Boric Acid Storage Tank A is in service, aligned to blend with level at 85%.

• POWERTRAX is NOT available.

Task Standard: Boron addition and BAST level change calculated within stated standards.

Required Materials: Station Curve Book Straight Edge EPP-5, Step 11 General

References:

EPP-5, Natural Circulation Cooldown, Revision 15 2011-2 NRCJPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Station Curve Book, Revision 197 Handouts: EPP-5, Step ii Initiating Cue: The ClSants to initiate boration while necessary support personnel are rorting. You have been directed to use Curve 1.14 to determine the/equired boron concentration for CSD (200 F) and then calculate the 5

boron addition necessary to achieve that boron concentration (with no allowance for PZR outsurge). In accordance with OP-30i, For large additions, ESTIMATE expected BAST level decrease for target boration.

Time Critical Task: NO Validation Time: 12 minutes 2011-2 NRCJPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 7 Form ES-C-i VERIFICATION OF COMPLETION (Denote Critical Steps with an asterisk)

Performance Step: I Determine minimum CSD Boron Concentration.

Standard: Determines Station Curve Book Curve 1.14 or Table 1.14 applies.

Examiners Note:

Comment:

• Performance Step: 2

/4 Determine minimum CSD Boron Conentration.

/\

IC (i T io9 )

Standard:

/

Reads no less than 1(6 PPM and no more than 146 PPM on Curve 1.14 or 1081 PPM from Table 1.14.

Examiners Note: The curve line falls between the 1050 PPM and the 1100 PPM Oø1

.11) line, allowing for a minor curve reading error since increments are 50 PPM. L Comment:

• Performance Step: 3 Determine the boron concentration change required.

00 5OO Standard: 1081 PPM600PPM481 PPM 754)

Examiners Note: 1056 PPM 600 PPM = 456 PPM 1106 PPM -600 PPM=506 PPM Comment:

2011-2 NRC JPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 7 Form ES-C-i VERIFICATION OF COMPLETION

• Performance Step: 4 Determine boration required.

Standard: Using Boron / Dilution Table 5.11 of the Station Curve Book, System Temperature of 547°F, calculated boric acid addition is 1195.9 gallons (1081 PPM)

Using FIGURE S-3.i-3 (Curve Book 5.3), BORON ADDITION-COOLANT HOT, determines minimum addition of no less than 1150 gallons.

Examiners Note: Based on PPM, boration volume will be 1132.6 gallons Based on 1$6 PPM, boration volume will be 1258.8 gallons IO95 Comment:

\\O4OV11 _--- L39 cMi

(? 7OO t

Q C) 5.

t7 2So,o (Oo

._L_.

I 7: \O 2011-2 NRC JPM RO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 7 Form ES-C-I VERIFICATION OF COMPLETION

• Performance Step: 5 For large additions, ESTIMATE expected BAST level decrease 4

for target boration.

Standard: Utilizing Station Curve 8.18; determines final BAST level to be no ,

greater than 62%.

Examiners Note: Calculation on Curve 8.18 as follows:

GALLONS to % LEVEL = (GALLONS 1024)152.36

% LEVEL to GALLONS = (% LEVEL)(52.36) + 1024 BAST level of 85% = 5474.6 gallons Volume of boric acid to be added to the RCS = >1132.6 gallons and <1 258.8 gallons.

5474.61195.9 = 4278.7 gallons which equates to a BAST level of 62.16%.

5474.6 1132.6

= 4342 gallons which equates to a BAST level of 63.4%.

5474.6 1258.8 = 4215.8 gallons which equates to a BAST level of 60.96%.

Comment:

LiTh; END OF TASK Terminating Cue: When the BAST Level estimate is complete, inform Candidate that the evaluation on this JPM is complete.

STOP TIME:

2011-2 NRC JPM RO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 7 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM RO A1-2 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 ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 7 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• The plant tripped from 50% RTP when a loss of off-s ite power occurred.

• The crew is performing EPP-5, Natural Circulation Coo ldown.

• The TSC is NOT staffed.

• Core Burnup is 11000 MWD/MTU

• Boron Concentration is 600 PPM

• Tavg is 54TF

• Boric Acid Storage Tank A is in service, aligned to blend with level at 85%.

• POWERTRAX is NOT available.

INITIATING CUE: The CRS wants to initiate boration while necessary supp ort personnel are reporting. You have been directed to use Curve 1.14 to determine the required boron concentration for CSD (200T) and then calculate the boron addition necessary to achieve that boron concentration (with no allowance for PZR outsurge). In accordance with OP-301, For large addi tions, ESTIMATE expected BAST level decrease for targe t boration.

201 1-2 NRC JPM RO A1-2 NUREG 1021, Revision 9, Supplement 1

EPP-5 NATURAL CIRCULATION COOLDOWN Rev. 15 Page 7 of 24 STEP INSTRUCTIONS I I RESPONSE NOT OBTAINED NOTE In the step below, the RCS mus t be over-borated to compen effects of a PZR outsurge. sate for the

11. Ensure Adequate Shutdown Marg in Exists As Follows;

a. Contact Plant Operations Staff to calculate the RCS Boron concentration required for Cold Shutdown allowing for a PZR outsurge

b. Check calculations COMPLETED

b. WHEN the calculations are completed. THEN Go To Step ll.c.

c. Check RCS Boron concentration

c. Perform the following:

- GREATER THAN REQUIRED

1) Borate RCS to cold shutdown boron concentration using OP301, Chemical And Volume Control System (CVCS)

2) Steam all intact S/Os for at least 30 minutes prior to sampling to ensure adequate chemical mixing.

3) Contact Chemistry to obtain periodic boron samples of the following:

• Reactor Coolant System

• Pressurizer

4) WHEN the RCS is at cold shutdown boron concentration, THEN Go To Step 12.

0 CURVE 1.14 REV. 197 HBR2 CYCLE 27 BORON CONCENTRATION REQUIRED TO MAINTAIN A MINIMUM OF 2.6% SHUTDOWN MARGIN (PPM) (ARI-M RR) 1500

\__ . -

L. -

1300 a .-.- -

z 0 1100 0

z CD z

900 -

0 c:\

0 I

D x

0

\\\

700 ---

38 F 200 F 300 F 350 F 500 0 2000 4000 6000 8000 10000 12000 14000 16000 CYCLE EXPOSURE (MWDIMTU)

REVIEWS ARE DOCUMENTED ELECTRON ICALLY IN THE PRR

TABLE 1.14 HBR2 CYCLE 27 BORON CONCENTRATION REQUIRED TO MAINTAIN A MINIMUM OF 2.6% SHUTDOWN MARGIN (PPM) (ARI-MRR)

Burnup (MWD/MTU)

Temp(F) 10300 10400 10500 10600 10700 10800 10900 11000 38 1138 1133 1129 1124 1119 1114 1110 1105 40 1138 1133 1128 1124 1119 1114 1109 1104 50 1136 1132 1127 1122 1117 1113 1108 1103 60 1135 1130 1125 1121 1116 1111 1106 1101 70 1133 1129 1124 1119 1114 1110 1105 1100 80 1132 1127 1122 1118 1113 1108 1103 1098 100 1129 1124 1120 1115 1110 1105 1100 1095 120 1126 1121 1117 1112 1107 1102 1097 1092 140 1123 1119 1114 1109 1104 1099 1095 1089 160 1121 1117 1112 1107 1102 1097 1092 1087 180 1119 1114 1109 1104 1100 1095 1090 1085 200 1116 1111 1106 1101 1096 1092 1086 1081 220 1112 1107 1103 1098 1093 1088 1083 1078 240 1108 1104 1099 1094 1089 1084 1079 1074 260 1104 1099 1094 1089 1084 1079 1074 1069 280 1099 1095 1090 1085 1080 1074 1069 1064 300 1094 1089 1084 1079 1074 1069 1064 1058 320 1089 1084 1079 1074 1068 1063 1058 1052 340 1083 1078 1073 1067 1062 1057 1052 1046 350 1079 1074 1069 1064 1059 1054 1048 1043 Source: PDD Figure 6.4-1 REV 197 Page 14 of 22 REVIEWS ARE DOCUMENTED ELECTRONICALLY IN THE PRR

(0 (0

- hi hi C) M iri C) p..,

C) C) 0 C.-)

C C) C) C, C) C) C-)

-C) ti Ci C) tn Qj hi ID O

o

[0 C) 0 t.io.

-3 h4

-i O

0 ...-....

0 tQ

.::: -i I-. I -

p., Vi J 0 . i) VI

.0 ... - --.,-

0 0.. C). C) .

C) .C)-0 - L.

0 0 CD 0 C) 0 0-0 P t-*tj - -

I I . I .

1.1. -L 1 1 I I I 1 I . 1 I I C-i . 4-. . .. C. .-.4 ....,

C 11

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0 0, C) 0 0 C) C) C) 0 b oc o . ci C) C)

• 0 C)

.(:.

Table 5.11 REQO GAL OF REQD GAL OF REQD GAL OF N Boron ACID REQD GAL OF REQD GAL OF REOD GAL OF WATER ACID WATER ACID Conc WATER ACID WATER ACID WATER TO TO TO TO ACID WATER (ppm) TO TO TO TO BORATE DILUTE BORATE DILUTE TO TO TO TO BORATE DILUTE BORATE DILUTE I PPM 1 PPM 5 PPM BORATE DILUTE BORATE DILUTE 5 PPM 10 PPM 10 PPM 20 PPM 600 2.5 83. 20 PPM 50 PPM 50 PPM 100 PPM 100 PPM 12.3 416. 24.6 836. 49.2 610 2.5 1686. 123.0 4,328. 246,) 9,068.

82. 12.3 409. 24.6 822.

620 2.5 49.2 1,658. 123.1 4,254.

80. 12.3 403. 24.6 246.5 8,905.

630 809. 49.2 1,631. 123.1 4,182.

2.5 79. 12.3 396. 24.6 246.6 8,748.

640 796. 49.2 1,605. 123.2 4,113.

2.5 78. 12.3 390. 24.6 246.7 8,597.

650 783. 49.3 1,579. 123.3 2.5 77. 12.3 384. 4,046. 246.8 8,450.

24.6 771. 49.3 1554.

650 2.5 75. 12.3 123.3 3,981. 246.9 8,309.

378. 24.7 759. 49.3 1,531.

670 2.5 74. 12.3 123.4 3,918. 247.1 8,172.

373. 24.7 748. 49.3 1,507.

680 2.5 73. 12.3 123.4 3,858. 247.2 8,040.

367. 24.7 737. 49.4 1,485.

690 2.5 72. 12.3 123.5 3,799. 247.3 7,912.

362. 24.7 726. 49.4 1,463. 123.6 3,741. 247.4 7,787.

700 2.5 71. 12.3 357. 24.7 716. 49.4 1,442.

710 2.5 70. 12.4 123.6 3,686. 247.5 7,667.

352. 24.7 706. 49.4 1,421.

720 2.5 69. 12.4 123.7 3,632. 247.7 7,550.

347. 24.7 696. 49.5 1,401.

730 2.5 68. 12.4 123.7 3,580. 247.8 7,437.

342. 24.7 686. 49.5 1,382.

740 2.5 67. 12.4 123.8 3,529. 247.9 7,328.

337. 24.7 677. 49:5 1,363.

750 2.5 66. 12.4 123.9 3,480. 248.0 7,221.

333. 24.8 668. 49.5 1,344.

760 2.5 65. 12.4 123.9 3,432. 248.1 7,118.

328. 24.8 659. 49.6 1,326.

770 2.5 65. 12.4 124.0 3,385. 248.3 7,017.

324. 24.8 650. 49.6 1,309.

780 2.5 64. 12.4 124.0 3,339. 248.4 6,919.

320. 24.8 642. 49.6 1.292.

790 2.5 63. 12.4 124.1 3.295. 248.5 6,824.

316 24.8 634. 49.6 1,275. 124.2 3,252. 248.6 6.732.,

800 2.5 62. 12.4 312. 24.8 626. 49.7 1,259.

810 25 61. 12.4 124.2 3,210. 248.7 6.642.

308. 24.8 618. 49.7 1,244.

820 2.5 61. 12.4 124.3 3,169. 248.9 6,554.

304. 24.8 610. 49.7 1,228.

830 2.5 60. 12.4 124.3 3,129. 249.0 6,469.

301. 24.9 603. 49.7 1,213.

840 2.5 59. 12.4 124.4 3,090. 249.1 6,385.

297. 24.9 O 850 860 870 2.5 2.5 2.5 59.

58.

57.

12.4 12.4 12.5 293.

290.

24.9 24.9 596.

58i 582 49.7 49.8 49.8 1.199.

1,184.

1,170.

124.5 124.5 124.6 3,052.

3,015.

2,979.

249.2 249.4 249,5 6,304.

6,225.

6,148.

287. 24.9 575. 49.8 1,157.

880 2.5 57 12.5 124.6 2,944. 249.6 6,073.

283. 24.9 568. 49.8 1.143.

890 2.5 56. 124.7 2,909. 249.7 6,000.

12.5 280. 24.9 662. 49.9 1,130. 124.8 2,876. 249.9 5,928.,

900 2.5 55. 12.5 277. 24.9 556. 49.9 1,118.

910 2.5 55. 124.8 2,843. 25QP 5,858.

12.5 274. 25.0 550. 49.9 920 2.5 54. 1,105. 124.9 2,811. 250.1 5,790.

12.5 271. 25.0 544, 49.9 930 2.5 1,093. 125.0 2.779. 250.2 5,723.

54. 12.5 268. 25.0 940 538. 50.0 1.081. 125.0 2,749.

2.5 53. 12.5 265. 25.0 250.3 5,658.

950 532. 50.0 1,070. 125.1 2,719.

2.5 52. 12.5 262. 250.5 5,594.

25.0 526. 50.0 1.058. 125.1 960 2.5 52. 12.5 260. 2,689. 250.6 5,532.

25.0 521. 50.0 1.047. 125.2 970 2.5 51. 12.5 257. 2,660. 250.7 5,471.

25.0 515. 50.1 1,036. 125.3 980 2.5 51. 12.5 2,632. 250.8 5,412.

254. 25.0 510. 50.1 1,026.

990 2.5 50. 12.5 125.3 2,605. 251.0 5,353.

252. 25.1 505., 50.1 1,015. 125.4 2,578. 251.1 5.296.

1,000 2.5 50. 12.5 249. 25.1 500. 50.1 1,005.

1,010 2.5 49. 12.5 125.4 2,551. 251.2 5,240.

247. 25.1 495. 50.2 1,020 2.5 49. 995. 125.5 2,525. 251.3 12.5 244. 25.1 490. 5,186.

1.030 2.5 50.2 985. 125.6 2,500. 251.5

48. 12.5 242. 25.1 485. 5,132.

1,040 2.5 50.2 975. 125.6 2.475. 251.6

48. 12.6 240. 25.1 481. 5,080.

1.050 2.5 50.2 966. 125.7 2,451.

47. 12.6 237. 25.1 251.7 5,028.

1.060 476. 50.3 957. 125.8 2.5 47. 12.6 235. 2,427. 251.8 4,978.

25.1 471. 50.3 947.

1,070 2.5 47. 12.6 125.8 2,403. 252.0 4.929.

233. 25.2 467. 50.3 1,080 2.5 46. 938. 125.9 2,380. 252.1 4,880.

12.6 231. 25.2 463.

1,090 2.5 50.3 930. 125.9 2,358.

46. 12.6 229. 25.2 458. 252.2 4,833.

50.4 921. 126.0 2,336. 252.3 4,786.

System Temperature = 547°F Rev. 183 Page 14 of 19

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Ro ;1 Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.:

Task

Title:

Perform Section 8.2.3 of OST-020, JPM No.: 2011-2 NRC JPM RO Shiftly Surveillances A2 K/A

Reference:

G2.2.37 3.6 /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: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

Task Standard: Identify all out of specification readings.

Required Materials: OST-020 General

References:

OST-020 Shiftly Surveillances, Revision 41 Handouts: OST-020

/0 Initiating Cue: You have relieved the OAC on the 07-i 900 watch due to a sudden illness. He was performing but unable to complete OST-020, Shiftly Surveillances. Perform Section 8.2.3, evaluate the acceptability of the instrument readings and document any unsatisfactory conditions in the comments section of Attachment 10.1.

Time Critical Task: NO Validation Time: 15 minutes 2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 2 of 9 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Examiners Cue: Provide OST-020 Cover Page through Section 7.0 and Section 8.2.3.

Performance Step: I Review procedure OST-020.

Standard: Reviews Precautions and Limitations and remainder of handout.

Examiners Note:

Comment:

Performance Step: 2 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.1)

1. PZR Level (Channels LI-459A, 460 and 461)

Standard: Candidate compares the channel readings and determines that all channels are within 5% for PZR level.

Examiners Note:

Comment:

2011-2 NRC JPM RO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 9 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 3 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.2)

2. PZR Pressure (Channels P 1-455, 456 and 457)

Standard: Candidate compares the channel readings and determines that channel P1-455 is outside of the tolerance of 40 psig from the other 2 channels.

Examiners Note:

Comment:

• Performance Step: 4 IF MODE 1,2 CR3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.3)

SIG Pressure for A SIG (Channels P 1-474, 475 and 476)

SIG Pressure for B SIG (Channels P1-484, 485 and 486)

SIG Pressure for C SIG (Channels P1-494, 495 and 496)

Standard: Candidate compares the channel readings and determines that channel P1-484 is outside of the tolerance of 70 psig from the other 2 channels for SIG B.

Examiners Note:

Comment:

2011-2 NRC JPM RO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 9 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 5 IF MODE 1,2 CR3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.4)

SIG Level for A SIG (Channels Ll-474, 475 and 476)

SIG Level for B S/G (Channels Ll-484, 485 and 486)

SIG Level for C SIG (Channels Ll-494, 495 and 496)

Standard: Candidate compares the channel readings and determines that channel Ll-475 is outside of the tolerance of 5% from the other 2 channels for SIG A.

Examiners Note:

Comment:

Performance Step: 6 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.5)

Steam Header Pressure (Channels PI-464A, 466 and 468)

Standard: Candidate compares the channel readings and determines all of the Steam Header pressure channels are within the tolerance of 70 psig.

Examiners Note:

Comment:

2011-2 NRC JPM RO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 9 Form ES-C-I PERFORMANCE INFORMATION Performance Step: 7 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.6)

SIG Steam Flows for S/G A (Chann&s FI-474 and 475)

S/C Steam Rows for SIG B (Channels Fl-484 and 485)

S/G Steam Flows for S/G C (Channels FI-494 and 495)

Standard: Candidate compares the channel readings and determines all of the Steam Flow channels are within tolerance.

Examiners Note:

Comment:

• Performance Step: 8 IF MODE 1, 2 CR3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.7)

Tavg (Channels TI-412D, 422D and 432D)

Standard: Candidate compares the channel readings and determines that channel Tl-432D is outside of the tolerance of 4°F from the other channels for Tavg.

Examiners Note:

Comment:

2011-2 NRCJPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 9 Form ES-C-I PERFORMANCE INFORMATION Performance Step: 9 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.8)

SI Accumulator A Level (LI-920 and 922)

SI Accumulator B Level (LI-924 and 926)

SI Accumulator C Level (LI-928 and 930)

Standard: Candidate compares the channel readings and determines all of the SI Accumulator level channels are within the tolerance of 5%.

Examiners Note:

Comment:

Performance Step: 10 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.9)

SI Accumulator A Pressure (P1-92 1 and 923)

SI Accumulator B Pressure (P1-925 and 927)

SI Accumulator C Pressure (P1-929 and 931)

Standard: Candidate compares the channel readings and determines all of the SI Accumulator pressure channels are within the tolerance of 40 psig.

Examiners Note:

Corn ment:

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 9 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: When the instrument readings have been evaluated and comments made for any out of spec readings, the evaluation on this JPM is complete.

STOP TIME:

2011-2 NRC JPM ROA2 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 RO A2 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 RO A2 NUREG 1021, Revision 9, Supplement 1

Section 8.2 Page 8 of 17 8.2.2.10 (Continued) iNil INJI 07-19 19-07

c. CALCULATE deviation: LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results ( 1.48). SAT I UNSAT (Circle one 8.2.3 IF MODE 1, 2, OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between the highest and lowest channel of redundant indicators for the same parameter. The redundant indicators to be compared are grouped in blocks. If the actual deviation is greater than the maximum allowed deviation as shown (deviation of 5% of the full range of the indicators movement, except for SIG Steam Flow when <20% rated thermal power), it is unacceptable. (ESR 97-00601)

1. PZR Level (ITS SR 3.3.1.1, Table 3.3.1-1 Item 8 and ITS SR 3.3.3.1, Table 3.3.3-1 Item 12)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER LI-459A RNP-I/INST-1060 LI-460 0-100% 5%

LI-461 OST-020 Rev. 41 Page 18 of 54

Section 8.2 Page 9 of 17 8.2.3 (Continued) INIT INIT 07-19 19-07

2. PZR Pressure IF Pressurizer Pressure is outside the indicating range due to normal plant conditions, THEN mark N/A.

(ITS SR 3.3.1.1, Table 3.3.1-1 Item 7.a, 7.b and ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.d and 6.a)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION NUMBER RANGE DEVIATION P1-455 RNP-I/INST-1042 P1-456 1700-2500 psig 40 psig P1-457

3. SIG Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.e, 1.g and 4.e, ITS SR 3.3.3.1, Table 3.3.3-1 Item 20)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-474 RNP-I/INST-1072 P1-475 0-1400 psig 70 psig P1-476 P1-484 RNP-I/INST-1072 P1-485 0-1400 psig 70 psig P1-486 P1-494 RNP-I/INST-1072 P 1-495 0-1400 psig 70 psig P1-4 96 OST-020 Rev. 41 Page 19 of 54

Section 8.2 Page 10 of 17 8.2.3 (Continued) INIT INIT 07-19 19-07

4. SIG Level (ITS SR 3.3.1.1, Table 3.3.1-1 Item 13 and 14, ITS SR 3.3.3.1, Table 3.3.3-1 Item 13, ITS SR 3.3.8.1, Table 3.3.8-1 Item 1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER LI-474 RNP-I/INST-1070 LI-475 0-100% 5%

LI-476 LI-484 RNP-I/INST-1070 LI-485 0-100% 5%

LI-486 LI-494 RNP-I/INST-1070 LI-495 0-100% 5%

LI-496

5. Steam Header Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.e)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER PI-464A RNP-I/INST-1050 P1-466 0-1400 psig 70 psig P1-468 OST-020 Rev. 41 Page 20 of 54

Section 8.2 Page 11 of 17 8.2.3 (Continued) INIT INIT 07-19 19-07

6. SIG Steam Flow (ITS SR 3.3.1.1, Table 3.3.1-1 Item 14 and ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.f, 1.g, 4.d and 4.e) (ESR 97-00601)

IF 20% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT RANGE MAXIMUM DEVIATION CALCULATION NUMBER FI-474 6 pph O-4x10 ph 0.2xlO p

6 RNP-I/INST-1040 FI-475 Fl-484 6 pph O-4x10 p 6 ph O.2xlO RNP-I/INST-1040 Fl-485 Fl-494 6 pph 0-4x10 ph 0.2xlO p

6 RNP-I/INST-1040 Fl-495 IF <20% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT RANGE MAXIMUM DEVIATION F 1-474 0-4x1 06 pph 0.4x1 O pph 6

FI-475 between the following combinations:

FI-474 AND FI-475

• FI 474 AND FI-477

• FI_475_AND_FI-476 FI-484 6 pph O-4x10 pph 6

O.4xlO Fl-485 between the following combinations:

FI-484 AND Fl-485

• FI 484 AND Fl-487

• FI_485_AND_FJ-486 FI-494 6 pph 0-4x10 pph 6

0.4xlO FI-495 between the following combinations:

Fl-494 AND Fl-495

• FI 494 AND Fl-497

• FI 495 AND FI-496 The Steam Flow Channel is checked against the corresponding Feed Flow channel for acceptance.

OST-020 Rev. 41 Page 21 of 54

Section 8.2 Page 12 of 17 8.2.3 (Continued) INIT INIT 07-19 19-07

7. Tavg IF Tavg is outside the indicating range due to normal plant conditions, THEN mark N/A.

(ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.f, 4.d and 6.b)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER TI-412D WCAP 11889 TI-422D 540-615°F 4°F TI-432D

8. SI Accumulator Level (TRMS TR 4.2.1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATTON RANGE DEVIATION NUMBER LI-920 0-100% 5% RNP-I/INST-1052 LI-922 LI-924 0-100% 5% RNP-I/INST-1 052 LI-926 LI-928 0-100% 5% RNP-IIINST-1052 LI-930

9. SI Accumulator Pressure (TRMS TR 4.2.1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-921 0-800 psig 40 psig RNP-I/INST-1036 P1-923 P1-925 0-800 psig 40 psig RNP-I/INST-1036 P1-927 P1-929 0-800 psig 40 psig RNP-I/INST-1 036 P1-93 1 OST-020 Rev. 41 Page 22 of 54

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Appendix C Page 9 of 9 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

/00 INITIATING CUE: You have relieved the QAC on the 07-1 900 watch due to a sudden illness. He was performing but unable to complete OST 020, Shiftly Surveillances. Perform Section 8.2.3, evaluate the acceptability of the instrument readings and document any unsatisfactory conditions in the comments section of Attachment 10.1.

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement I

P3 Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.:

Task

Title:

Calculate the Maximum Permissible JPM No.: 2011-2 NRC JPM Admin Stay Time with Emergency Dose Limits RO A3 K/A

Reference:

G2.3.4 (3.2/3.7)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator 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:

• An emergency event has been declared.

• A Containment entry would enhance the pressure control of the plant but is NOT required to protect valuable plant equipment.

• The tasks to be performed are:

Task Task Time Dose Number Required Rate (R/hr)

(minutes) 1 Fail closed PCV-455A 8 21.42 2 Manually open RC-536 6 3.65 3 Manually close CVC- 9.51 312 NOTE: Assume that NO dose is received while traveling between the tasks.

Task Standard: Calculate the dose received and the maximum time allowed to perform the final task (+1, -3 minutes)

Required Materials: Calculator NGGM-PM-0002 General

References:

NGGM-PM-0002, EPCLA-Oi 2011-2 NRC JPM Admin ROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Handouts: NGGM-PM-0002, EPCLA-Oi Initiating Cue: The Inside Auxiliary Operator has completed Tasks #1 and 2 in the time required.

How long does he have to complete Task #3 without exceeding the applicable Emergency Dose Limit?

Time Critical Task: NO Validation Time: 10 minutes SIMULATOR SETUP N/A 2011-2 NRC JPM Admin RO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 7 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

START TIME:

Performance Step: I Determine the dose received while performing Task #1.

Standard: Candidate determines the dose received while performing Task

1. 1:

21.42 R/hr X 8 minutes X 1 hour/60 minutes = 2.856 R.

Examiners Note: Provide the candidate a copy of EPCLA-O1.

Comment:

Performance Step: 2 Determine the dose received while performing Task #2.

Standard: Candidate determines the dose received while performing Task

1. 2:

3.65 R/hr X 6 minutes X I hour/60 minutes =0.365 R.

Examiners Note:

Comment:

2011-2 NRC JPMAdmin ROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 7 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 3 Determine the remaining dose to reach the Emergency Dose Limit.

Standard: Candidate calculates the dose remaining for the Emergency Dose Limit:

5.00 R 2.856 R 0.365 R = 1.779 R Examiners Note:

Comment:

• Performance Step: 4 Determine the time available for the Inside Auxiliary Operator to complete Task #3 with exceeding the Emergency Dose Limit.

Standard: Candidate determines within +1, 3 minutes the time available for the Inside Auxiliary Operator to complete Task #3 without exceeding the Emergency Dose Limit:

Available Dose! Dose Rate = 1.779 R/9.51 R/hr 0.187 hrs 0.187 hrs X 60 minutes!1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 11.22 minutes (+1, - 3 mh9üts))

L_-?Qcc5 Examiners Note:

1I &ts Comment:

yr 2011-2 NRC JPMAdmin ROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 7 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Termination Cue: When the candidate has calculated the allowable dose for Task #3, the evaluation of this JPM is complete.

STOP TIME:

2011-2 NRC JPMAdmin ROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 7 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM Admin RO A3 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 Admin RO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 7 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• An emergency event has been declare d.

• A Containment entry would enhance the pressure control of the plant but is NOT required to protect valu able plant equipment.

• The tasks to be performed are:

Task Task Time Dose Number Required Rate (RIhr)

(minutes) 1 Fail closed PCV-455A 8 21.42 2 Manually open RC-536 6 3.65 3 Manually close CVC-9.51 312 NOTE: Assume that NO dose is rece ived while traveling between the tasks.

INITIATING CUE: The Inside Auxiliary Operator has com pleted Tasks #1 and 2 in the time required.

How long does he have to complete Tas k #3 without exceeding the applicable Emergency Dose Limit?

2011-2 NRC JPM Admin RO A3 NUREG 1021, Revision 9, Supplement 1

k2 A/-i Appendix C Job Performance Measure Form ES-C-i Worksheet Facility

HB ROBINSON Task No.: 02341101103 Task

Title:

Heat Stress Work Limits JPM No.: 2011-2 NRC JPM SRO Al-I K/A

Reference:

G2.1.26 3.4/3.6 Examinee:

NRC Examiner:

Facility Evaluator:

Date:

Method of testing:

Simulated Performance:

Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simu late 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 with RCS cooldown in progress.

• RHR System needs to be aligned for core cooling lAW GP-007 and OP-201

• 2 ACs have been briefed on performing the valve align ments.

• Work time is 30 minutes per AC (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> total)

• RC has determined that OREX coveralls will be used.

Task Standard: Candidate is to determine the following:

• Metabolic heat load

• Action time in minutes

• Recovery period in minutes Required Materials: AP-020, Heat Stress Program, Revision 16 General

References:

AP-020, Heat Stress Program Handouts: AP-020, Heat Stress Program Initiating Cue: Using AP-020, Complete Attachment 10.3 to determine the metabolic heat load, allowable working time and recovery period for work in the specified plant area. Additional information on CUE shee t.

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-I Worksheet Time Critical Task: NO Validation Time: 12 minutes 2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 8 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk Start Time:

Performance Step: I Candidate reviews AP-020 Attachment 10.3, Heat Stress Evaluation Form Standard: Candidate reviews AP-020 Attachment 10.3, Heat Stress Evaluation Form Examiners Note:

Comment:

Performance Step: 2 Determine the correct clothing for the type of job. (Step 8.1.4)

Standard: Candidate determines that Attachment 10.2, Page 4 of 11, OREX over Scrub Suit (CS) or SMS polypropylene coveralls (PP) over Scrub Suit (CS) is the proper attachment to be used in the heat stress determination.

Examiners Note:

Comment:

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 8 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 3 Determines the Metabolic Heat Load to be Moderate Work.

(Step uses Attachment 10.1)

Standard: Candidate determines performing valve alignments to be Moderate Work Examiners Note:

Comment:

Performance Step: 4 Determines the temperature in the Auxiliary Building Pipe Alley Standard: Candidate circles Estimate for WBGT on Attachment 10.3 Examiners Note: Candidate uses Attachment 10.4, Estimating WBGT to estimate WBGT from dry temperature.

Comment:

• Performance Step: 5 Determines WBGT to be 101°F Standard: Candidate determines WBGT to be Dry bulb plus 4°F from Attachment 10.4 (97°F +4°F =101°F)

Examiners Note:

Comment:

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 8 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 6 Determines Action Time to be 35 minutes Standard: Candidate uses Attachment 10.2 to determine Action Time to be 35 minutes. Page 4 of 11, Recommended Heat Stress Control Action Times OREX Over Scrub Suit (CS) for Moderate Work at 101°F WBGT Examiners Note:

Comment:

• Performance Step: 7 Determines the Recovery time to be 51 minutes (Step 8.3.1)

Standard: Candidate uses 30 minutes as time in hot environment (2 men working for 1.0 person hour)

(30*60)/35 = (1800/35) 51.4 Minutes (Range of 51 to 52 minutes)

Examiners Note:

Comment:

Performance Step: 8 Circles YES for the workers have received a pre-job brief including Heat Stress Concerns Standard: Candidate circles YES, this information was in the initial conditions.

Examiners Note:

Comment:

Performance Step: 9 Sign and Date Attachment 10.3 Standard: Candidate reviews and then signs and dates Attachment 10.3 Examiners Note:

Comment:

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement I

Appendix C Page 6 of 8 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: Candidate completes Heat Stress Evaluation Form STOP TIME:

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement I

Appendix C Page 7 of 8 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC Admin JPM SRO Al-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 Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 8 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• Plant is in Mode 3 with RCS cooldown in progress.

• RHR System needs to be aligned for core cooling lAW GP-0 07 and OP-20 1

• 2 AOs have been briefed on performing the valve align ments.

• Work time is 30 minutes per AC (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> total)

• RC has determined that OREX overalls will be used.

INITIATING CUE: Using AP-020, Complete Attachment 10.3 to determine the metabolic heat load, allowable working time and recovery period for work in the specified plant area.

Work to be performed Valve alignments in overhead Pipe Alley Thermometer: 97°F Relative Humidity: Not Available Pipe Alley is a Contaminated Area 2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement I

Pagss Erergy INFORMATION H. B. ROBINSON STEAM ELECTRIC PLA NT, UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 1 PART 1 AP-020 HEAT STRESS PROGRAM REVISION 16 AP-020 Rev. 16 Page 1 of 33

SUMMARY

OF CHANGES PRR 00476573 AP-020 REVISION 16 STEPISECTION REVISION COMMENTS Attachment 10.2 Updated NOTE to include (refer to 8.4.2) for PCR references Editorial AP-020 Rev. 16 Page 2 of 33

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE 4

2.0 REFERENCES

4 3.0 RESPONSIBILITIES 4

4.0 PREREQUISITES 6

5.0 PRECAUTIONS AND LIMITATIONS 7

6.0 SPECIAL TOOLS AND EQUIPMENT 8

7.0 ACCEPTANCE CRITERIA 8

8.0 INSTRUCTIONS 8.1 Heat Stress Evaluation 9 8.2 Use of Recommended Action Times 9 8.3 Determination of Recovery Period Times 10 8.4 Use of Personal Cooling Devices 11 8.5 Use of Supplied Air Hoods 11 8.6 First Aid For Heat Illness 12 12 9.0 RECORDS 14 10.0 ATTACHMENTS 10.1 METABOLIC HEAT LOAD GUIDELINES 14 10.2 RECOMMENDED HEAT STRESS CONTROL 15 ACTION TIMES 16 10.3 HEAT STRESS EVALUATION FORM 10.4 ESTIMATING WBGT 27 10.5 USING THE WET BULB GLOBE THERMOMET 28 ER 29 10.6 HEAT STRESS PRE-JOB BRIEFING 10.7 DEFINITIONS 30 31 AP-020 Rev. 16 Page 3 of 33

1.0 PURPOSE 1.1 The purpose of this procedure is to provide guidance to management and all employees for preventing heat-induced illnesses while performing work activities on the plant site.

2.0 REFERENCES

2.1 EPRI NP-4453-L, Heat Stress Management Program for Nuclear Power Plants Revision 1, Aug. 1991.

2.2 Clothing Update of EPRI NP-4453-L, 1991 Report, TR-1 09445, Final Report, July 1998.

2.3 CP&L Corporate Guidance Document SAF-CPL-032 Heat Stress.

2.4 NCR 49246, Use Of Tube Suits 3.0 RESPONSIBILITIES 3.1 Section Managers - Robinson Plant are responsible for:

3.1.1 Ensuring that personnel who perform work in moderate

/high heat stress work environment(s) follow the guidelines in this procedur e.

3.1.2 Ensuring that supervisors follow this the guidelines in this proc edure when planning work in moderate/high heat stress work envi ronments.

3.2 Supervisors are responsible for:

3.2.1 Ensuring that heat stress mitigation has been considere d during job planning. The work crew supervisor or designee shall deter mine the Wet Bulb Globe Temperature and metabolic heat load using the guidance available in Attachments 10.1, 10.2 and 10.6.

3.2.2 Ensuring that either Attachment 10.3, Heat Stres s Evaluation Form is completed, OR that proper means of determining actio n times and control measures have taken place and have been includ ed as part of pre-job planning when Heat Stress has been determine d to be an issue.

f AP-020 Rev. 16 Page 4 of 33

3.2.3 Ensuring that a pre-job briefing is conducted prior to workers entering high temperature environment the to perform work. The Precautio Limitations found in section 5.1 ns and of this procedure should be covere the briefing. d in 3.2.4 Ensuring that proper control me thods are used to protect against hea stress. t 3.2.5 Ensuring that all heat-stress cau sed incidents which require medical attention are recorded on FRM

-SUBS-00979, Injury and Illness Inc Report Form. These forms can ident be obtained on the Progress Energy Intranet.

3.3 Individuals are responsible for:

3.3.1 Following instructions for the han dling of body cooling devices and them as needed to prevent hea using t stress.

3.3.2 Being attentive to sym ptoms of heat stress while workin moderate/high heat stress wor g in k environments, stopping work, leav in a safe condition, and exiting the ing it hot environment, if they feel ill due heat stress. to 3.3.3 Reporting to their supervisor any occurrence of heat stress or hea related illness. t 3.3.4 Reporting to their supervisor any condition that might adversely imp their ability to perform their dut act ies as a Fire Brigade Member. Th conditions include but are not ese limited to general health, illness, medications, etc.

3.4 RC Unit is responsible for:

3.4.1 Providing Ice vests for work acti vities inside the RCA.

3.5 Unit 2 Control Room personnel are responsible for ensuring action provide first aid or medical atte s are taken to ntion when notified of conditions stress victims. involving heat AP-020 Rev. 16 Page 5 of 33

3.6 Site Industrial Hygiene and Safety Representative is responsible for:

3.6.1 Providing technical assistance on heat stress issues, including the development of plant heat stress training programs and maintenance of this procedure.

3.6.2 Ensuring that instruction on heat stress mitigation is arranged and conducted for employees prior to initial work in high temperature environments.

3.6.3 Assisting supervisors in the implementation of this procedure, when requested.

3.7 Maintenance is responsible for:

3.7.1 Maintaining and issuing Tube Suits.

40 PREREQUISITES N/A AP-020 Rev. 16 Page 6 of 33

5.0 PRECAUTIONS AND LIMITATIONS NOTE: These precautions should be covered in employee training as well as in the pre-job briefings prior to performing moderate or high heat stress work.

During time-critical evolutions involving emergency response where the safety of personnel and the public is a critical issue, personnel may not be able to comply with all of the requirements of this procedure. All reasonable attempts should be made to ensure the safety of personnel involved in the emergency response without compromising the timely completion of the response.

5.1 If an individual begins to feel symptoms of heat illness, the person should put their work in a safe condition, exit the area, notify their supervisor, rest in a cool area, and drink fluids. The Control Room should be called at ext. 5555 if symptoms persist in order to dispatch appropriate site first aid providers.

5.2 All jobs in high temperature environments should address heat stress controls in the planning stages. Planned action times and the use of body cooling device s

should be considered.

5.3 Individuals who work in high temperature environments for the first time are more susceptible to heat illness than those accustomed to hot environments. After working in hot environments for several days, their bodies tend to acclimatize to heat exposure and they may tolerate longer heat exposures at higher work rates.

5.4 Work shall be planned so that an adequate number of workers are prepared to work in a high temperature environment. Workers should never work alone in high heat stress areas.

5.5 Individuals vary greatly in their tolerance to heat exposure. Factors which may affect heat tolerances may include:

• Age

• Weight

• Sex

• physical fitness

• general health

• colds, viruses, and infections

• some medications

• consumption of alcoholic beverages AP-020 Rev. 16 Page 7 of 33

5.6 In situations where individuals know that their work schedule for the following day involves entering a heat stress area, they should drink plenty of liquids in the 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to reporting to work.

5.7 Whenever feasible, engineering controls should be used to eliminate/reduce the heat exposure (i.e., isolation of the heat source, introduction of cooled air, circulation of present air, reduced humidity, etc.). The impact of these engineering controls should be reviewed with the Radiation Control (RC) unit for jobs in radiologically controlled areas.

5.8 Individuals who work in high temperature environments may become dehydrated due to sweating. Lost body water and electrolytes should be replaced at rest breaks to prevent heat-related illness. Liquids designed to replace these electrolytes (gatorade) may be obtained from the bulk warehouse prior to or after entry, and should be consumed in frequent, small amounts. (Salt tablets are not recommended.)

5.9 Individuals who work in high temperature environments must periodically rest in a cooler area to shed body heat. Duration of breaks, extent of clothing removal, and rest area should be determined by the job supervisor, using the guidance in Step 8.3.1. Certain employees may require longer rest periods than others.

5.10 Workers should be encouraged to drink one pint of water/fluid per hour of scheduled work prior to entering high heat stress areas.

5.11 Workers should also be encouraged to drink water/fluids after high temperature work to maintain fluid balance.

5.12 Where feasible, high heat stress work should be scheduled to minimize thermal stress in the work area. This includes scheduling work at times where the WBGT and/or the metabolic heat load are lower and/or protective clothing requirements are less restrictive.

5.13 For pre-job briefings in heat stress related work areas, utilize Attachment 10.6 during the briefing.

6.0 SPECIAL TOOLS AND EQUIPMENT N/A 7.0 ACCEPTANCE CRITERIA N/A AP-020 Rev. 16 Page 8 of 33

8.0 INSTRUCTIONS 8.1 Heat Stress Evaluation 8.1.1 The heat stress evaluation process involves assessing the variables that effect heat stress, including WBGT measurements, metabolic work load, clothing type and recovery periods. These factors are converted to recommended action times without regard to personal cooling devices for job planning purposes. A Heat Stress Evaluation Form, Attachment 10.3, may be used for heat stress job planning.

NOTE: The Temperature/Relative Humidity meters should be placed in the shade, where possible. These meters may display inaccurate readings if in direct sunlight (higher than actual temperature and lower than actual relative humidity). The crew supervisor/designee should contact the Site Industrial Hygiene and Safety Representative for assistance in conducting Heat Stress Evaluations.

8.1.2 The work crew supervisor/designee should measure the WBGT of the work area when hefshe feels that heat stress conditions may exist.

WBGT is calculated using the following WBGT formulas:

Indoor WBGT = (0.7 x wet bulb) + (0.3 x globe)

Outdoor WBGT = (0.7 x wet bulb) + (0.2 x globe) + (0.1 x dry bulb)

Initial WBGT readings should be made with a Wet Bulb Globe Thermometer, available from the calibration lab. Instructions for the use of the Wet Bulb Globe Thermometer are found on Attachment 10.5, Using the Wet Bulb Globe Thermometer. Measurements should be representative of the work area thermal load. Succeeding evaluations may be based solely on dry bulb temperature and relative humidity by using Attachment 10.4, Estimating WBGT. Temperature/Relative Humidity meters are posted at various locations around site to assist with conducting these estimates. Charts on these meters have been developed in accordance with Attachment 10.4, and should be consulted to assist in the estimation of WBGT.

AP-020 Rev. 16 Page 9 of 33

8.1.3 The work crew supervisor/designee should deter mine the metabolic heat load using the guide available in Attachment 10.1 8.1.4 The work crew supervisor/designee should deter mine the type of work clothing required or being used for the job. The categories include; work clothes (WC), cloth coveralls (CC), cloth coveralls over scrub suit (CS),

double cloth coveralls (DC), OREX coveralls, SMS polypropylene coveralls (PP), MB polyethylene coveralls (PE), poly ester coveralls (P2),

polyester coveralls with scrubs (PS), water-barrier vapor-permeable coveralls (WB-1), water barrier vapor-permeable coveralls (WB-2),

vapor-barrier coveralls (VB), encapsulating suit or turn-out gear (ES),

flame retardant shirt and pants (FR).

8.2 Use of Recommended Action Times 8.2.1 Knowing the WBGT measurements, metabolic heat load, and protective clothing used, the work crew supervisor or desig nee should determine the planned action time from Attachment 10.2 and identify the desired methods to mitigate heat stress if longer work time s are necessary.

8.2.2 Action times are used for job planning

. Action times are absolute because of the great variability in worker response to heat-stress. Some workers could experience heat stress symptom s prior to reaching the maximum action time.

8.2.3 By using the planned action time limits and assessing the physical condition of the workers, the work crew superviso r or designee can determine how long his workers can be expected to work before rest breaks should be given. Workers have the right to and should immediately exit the hot environment prior to the time limit if they begin to experience heat stress symptoms.

8.2.4 If there are changes in the WBGT, the meta bolic work load category, or the required clothing type during the course of the job, then a re evaluation of the job action time is necessary.

8.2.5 Absolute Stay Time will be two times the Recommended Action Time lAW Attachment 10.2 and EPRI guidelines.

AP-020 Rev. 16 Page 10 of 33

8.3 Determination of Recovery Period Times 8.3.1 When work cannot be completed in the estimated action time, the supervisor must calculate an appropriate recovery period for workers to dissipate excess heat and replace water. Recovery should take place in a cool location (less than 80 degrees F.) where drinking water or gatorade is available. The length of recovery period depends on the length of exposure and the action time of the job. Recovery periods of up to one hour may be necessary for jobs which approach or exceed the planned action times. The following formula should be used as a guide for determining the minimum length of recovery period. All times are in minutes.

REC= AET x 60 MST REC Recovery Time AET Actual Exposure Time to the Hot Environment MST Appropriate Action Time determined from Attachment 10.2 8.4 Use of Personal Cooling Devices CAUTION The personal cooling device should not be donned until just prior to entering the hot environment. The ice vest or Tube Suit will provide body cooling only while the ice is melting. Once the ice has melted, body temperature will increase quickly.

Workers should monitor their condition and exit the work area as soon as the ice vest has lost its cooling effectiveness.

8.4.1 By using Attachment 10.2, Recommended Heat Stress Control Action Times, the work crew leaders supervisor can determine if personal cooling devices would be beneficial for the job.

8.4.2 Individual workers should have the option of wearing a personal cooling device for any job when they feel there is a need. If a personal cooling device is worn, then the recommended action time is 60 minutes or until the ice melts.

AP-020 Rev. 16 Page 1 1 of 33

8.4 (Continued) 8.4.3 Ice vests are available in dressout areas in the Radiation Contro l Area.

8.4.4 The ice vest should be worn so that the vest fits snugly. A t-shirt should be worn under the vest.

8.4.5 Tube Suits are available in the Maintenance Shop.

CAUTION Use of supplied air hoods results in forced air cooling of the head, but not the body.

This can lead to a false sense of body cooling, and delayed awareness of heat stress by the hood user.

8.5 Use of Supplied Air Hoods 8.5.1 Supplied air hoods are used mainly as respirators and their uses are authorized only by the Radiation Control Unit.

8.5.2 When authorized for use, supplied air hoods will supply respirable air and cooling air to the head. Normal action times per Attachment 10.2 are applicable.

8.6 First Aid For Heat Illness 8.6.1 If any individual begins to feel symptoms of heat illness, then the person should immediately exit the area, notify the supervisor, rest in a cool area, and drink fluids. The Control Room (ext. 5555) should be called if symptoms persist.

8.6.2 Examples of symptoms that should necessitate calling the Contro l Room are as follows:

- Pulse rate does not decrease in 30-45 minutes

- Unconsciousness

- Cannot drink fluids without vomiting

- Heat stroke

- Any other symptom deemed to be of concern.

8.6.3 The individual in the Control Room who receives the call shall take appropriate actions to ensure further first aid and/or medical attenti on is provided.

AP-020 Rev. 16 Page 12 of 33

8.6.4 The following first aid actions should be taken at the first sign of heat stress symptoms.

Heat Illness occurs due to an increased body temperatu re and/or a loss of body fluids and salts.

First Aid Rest in cool area, drink water or other liquids to replace body fluids, and eat food high in salt content.

2. Heat Cramps are muscle spasms due to a loss of salt throu gh sweating. Leg, stomach, and back muscles are most often affected and are often a sign of approaching heat exha ustion.

Cramps can also result from drinking large amounts of wate r

without electrolytes (salt, sugar).

First Aid: Rest in cool area, drink water or other liquids

, and eat food high in salt content.

3. Heat Exhaustion Condition caused by an insufficient flow of blood to the brain (blood is shunted to the skin to lose heat)

Symptoms can include cool, pale clammy skin, weakness dizziness, headache, nausea, and fainting.

First Aid: Rest in cool area, lie down, elevate feet, appl y cool wet cloths, fan with air, and drink liquids.

4. Heat Stroke a serious medical emergency caused by failure a of the bodys cooling mechanisms. Symptoms include hot, dry skin (sweating stops), extremely high body temperatures, stron g, rapid pulse, and unconsciousness.

First Aid: Immediate, rapid cooling of the body is necessary

. Use safety showers, move air over the body with a fan or by fann ing, or cover the body with a wet sheet. Seek immediate med ical attention.

AP-020 Rev. 16 Page 13 of 33

9.0 RECORDS N/A 10.0 ATTACHMENTS 10.1 Metabolic Heat Load Guidelines 10.2 Recommended Heat Stress Control Action Times 10.3 Heat Stress Evaluation Form 10.4 Estimating WBGT 10.5 Using the Wet Bulb Globe Thermometer 10.6 Heat Stress Pre-Job Briefing AP-020 Rev. 16 Page 14 of 33

ATTACHMENT 10.1 Page 1 of I METABOLIC HEAT LOAD GUIDELINES LIGHT WORK Light work are those average demands that are typical of job supervision, inspec tions, instrument repair and calibration, surveying. Light work can be performed indefinitely by everyone.

MODERATE WORK Moderate work are those average demands that are typical of a system walk-d own, valve alignments, valve and motor repairs, and light materials handling. Under cool conditions, moderate work can be easily performed by most people if there is a 10-minute break every hour. Most physically demanding work falls into this catego ry.

HEAVY WORK Heavy work are those average demands that are typical of gross decontaminat ion, heavy materials handling, and extensive ladder and stair climbing. Even in comfortable conditions, heavy work can be sustained by most people for no more than 60 minutes.

It is not often that heavy work is the appropriate classification because rest breaks will reduce the overall demand to the moderate category.

f AP-020 Rev. 16 Page 15 of 33

ATTACHMENT 10.2 Page 1 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES WORK CLOTHES (WC) (Cotton)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 81 NL NL NL 82 NL NL 240 83 NL NL 150 84 NL 240 120 85 NL 210 100 86 NL 165 90 87 NL 135 80 88 NL 110 70 89 240 95 65 90 230 85 55 91 215 80 50 92 200 70 45 93 180 65 40 94 165 55 40 95 150 50 35 96 130 50 35 97 115 45 30 98 110 40 25 99 100 40 25 100 90 35 20 101 85 35 20 102 75 35 20 103 65 30 20 104 60 30 15 105 55 25 PCR 106 50 25 PCR 107 50 25 PCR 108 45 25 PCR 109 40 20 PCR 110 35 20 PCR 111 30 20 PCR 112 30 20 PCR 113 25 20 PCR 114 25 15 PCR 115 25 15 PCR 116 25 PCR PCR 117 20 PCR PCR 118 20 PCR PCR 119 20 PCR PCR 120 20 PCR PCR 121 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 16 of 33

ATTACHMENT 10.2 Page 2 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES CLOTH COVERALLS OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 73 NL NL NL 74 NL NL 240 75 NL NL 150 76 NL 240 120 77 NL 210 100 78 NL 165 90 79 NL 135 80 80 NL 110 70 81 240 95 65 82 230 85 55 83 215 80 50 84 200 70 45 85 180 65 40 86 165 55 40 87 150 50 35 88 130 50 35 89 115 45 30 90 110 40 25 91 100 40 25 92 90 35 20 93 85 35 20 94 75 35 20 95 65 30 20 96 60 30 15 97 55 25 PCR 98 50 25 PCR 99 50 25 PCR 100 45 25 PCR 101 40 20 PCR 102 35 20 PCR 103 30 20 PCR 104 30 20 PCR 105 25 20 PCR 106 25 15 PCR 107 25 15 PCR 108 25 PCR PCR 109 20 PCR PCR 110 20 PCR PCR 111 20 PCR PCR 112 20 PCR PCR 113 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 17 of 33

ATTACHMENT 10.2 Page 3 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES DOUBLE CLOTH COVERALLS (DC) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 69 NL NL NL 70 NL NL 240 71 NL NL 150 72 NL 240 120 73 NL 210 100 74 NL 165 90 75 NL 135 80 76 NL 110 70 77 240 95 65 78 230 85 55 79 215 80 50 80 200 70 45 81 180 65 40 82 165 55 40 83 150 50 35 84 130 50 35 85 115 45 30 86 110 40 25 87 100 40 25 88 90 35 20 89 85 35 20 90 75 35 20 91 65 30 20 92 60 30 15 93 55 25 PCR 94 50 25 PCR 95 50 25 PCR 96 45 25 PCR 97 40 20 PCR 98 35 20 PCR 99 30 20 PCR 100 30 20 PCR 101 25 20 PCR 102 25 15 PCR 103 25 15 PCR 104 25 PCR PCR 105 20 PCR PCR 106 20 PCR PCR 107 20 PCR PCR 108 20 PCR PCR 109 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

APO2O Rev. 16 Page 18 of 33

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ATTACHMENT 10.2 Page 5 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES MB POLYETHYLENE COVERALLS (PE) (Tyvek 1422A OVER

) SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 76 NL NL NL 77 NL NL 240 78 NL NL 150 79 NL 240 120 80 NL 210 100 81 NL 165 90 82 NL 135 83 80 NL 110 70 84 240 95 65 85 230 85 55 86 215 80 50 87 200 70 45 88 180 65 40 89 165 55 40 90 150 50 35 91 130 50 35 92 115 45 30 93 110 40 25 94 100 40 25 95 90 35 20 96 85 35 20 97 75 35 20 98 65 30 20 99 60 30 15 100 55 25 PCR 101 50 25 PCR 102 50 25 PCR 103 45 25 PCR 104 40 20 PCR 105 35 20 PCR 106 30 20 PCR 107 30 20 PCR 108 25 20 PCR 109 25 15 110 PCR 25 15 PCR 111 25 PCR 112 PCR 20 PCR PCR 113 20 PCR PCR 114 20 PCR PCR 115 20 PCR 116 PCR PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 20 of 33

ATTACHMENT 102 Page 6 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES POLYESTER COVERALLS (P2) (ProTech 2000) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 76 NL NL NL 77 NL NL 240 78 NL NL 150 79 NL 240 120 80 NL 210 100 81 NL 165 90 82 NL 135 80 83 NL 110 70 84 240 95 65 85 230 85 55 86 215 80 50 87 200 70 45 88 180 65 40 89 165 55 40 90 150 50 35 91 130 50 35 92 115 45 30 93 110 40 25 94 100 40 25 95 90 35 20 96 85 35 20 97 75 35 20 98 65 30 20 99 60 30 15 100 55 25 PCR 101 50 25 PCR 102 50 25 PCR 103 45 25 PCR 104 40 20 PCR 105 35 20 PCR 106 30 20 PCR 107 30 20 PCR 108 25 20 PCR 109 25 15 PCR 110 25 15 PCR 111 25 PCR PCR 112 20 PCR PCR 113 20 PCR PCR 114 20 PCR PCR 115 20 PCR PCR 116 PCR PCR PCR NOTES: NL = No Limit, PCR Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 21 of 33

ATTACHMENT 10.2 Page 7 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES WATER-BARRIER, VAPOR-PERMEABLE COVERALLS (WB-1) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 68 NL NL NL 69 NL NL 240 70 NL NL 150 71 NL 240 120 72 NL 210 100 73 NL 165 90 74 NL 135 80 75 NL 110 70 76 240 95 65 77 230 85 55 78 215 80 50 79 200 70 45 80 180 65 40 81 165 55 40 82 150 50 35 83 130 50 35 84 115 45 30 85 110 40 25 86 100 40 25 87 90 35 20 88 85 35 20 89 75 35 20 90 65 30 20 91 60 30 15 92 55 25 PCR 93 50 25 PCR 94 50 25 PCR 95 45 25 PCR 96 40 20 PCR 97 35 20 PCR 98 30 20 PCR 99 30 20 PCR 100 25 20 PCR 101 25 15 PCR 102 25 15 PCR 103 25 PCR PCR 104 20 PCR PCR 105 20 PCR PCR 106 20 PCR PCR 107 20 PCR PCR 108 PCR PCR - PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 22 of 33

ATTACHMENT 10.2 Page 8 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES WATER-BARRIER VAPOR-PERMEABLE COVERALLS (WB-2) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light I Moderate Heavy 74 NL NL NL 75 NL NL 240 76 NL NL 150 77 NL 240 120 78 NL 210 100 79 NL 165 90 80 NL 135 80 81 NL 110 70 82 240 95 65 83 230 85 55 84 215 80 50 85 200 70 45 86 180 65 40 87 165 55 40 88 150 50 35 89 130 50 35 90 115 45 30 91 110 40 25 92 100 40 25 93 90 35 20 94 85 35 20 95 75 35 20 96 65 30 20 97 60 30 15 98 55 25 PCR 99 50 25 PCR 100 50 25 PCR 101 45 25 PCR 102 40 20 PCR 103 35 20 PCR 104 30 20 PCR 105 30 20 PCR 106 25 20 PCR 107 25 15 PCR 108 25 15 PCR 109 25 PCR PCR 110 20 PCR PCR 111 20 PCR PCR 112 20 PCR PCR 113 20 PCR PCR 114 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 23 of 33

ATTACHMENT 10.2 Page 9 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES VAPOR-BARRIER COVERALLS (VB) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 64 NL NL NL 65 NL NL 240 66 NL NL 150 67 NL 240 120 68 NL 210 100 69 NL 165 90 70 NL 135 80 71 NL 110 70 72 240 95 65 73 230 85 55 74 215 80 50 75 200 70 45 76 180 65 40 77 165 55 40 78 150 50 35 79 130 50 35 80 115 45 30 81 110 40 25 82 100 40 25 83 90 35 20 84 85 35 20 85 75 35 20 86 65 30 20 87 60 30 15 88 55 25 PCR 89 - 50 25 PCR 90 50 25 PCR 91 45 25 PCR 92 40 20 PCR 93 35 20 PCR 94 30 20 PCR 95 30 20 PCR 96 25 20 POR 97 25 15 FOR 98 25 15 POR 99 25 POR POR 100 20 FOR POR 101 20 FOR FOR 102 20 FOR POR 103 20 POR FOR 104 FOR POR POR NOTES: NL = No Limit, POR = Personal 000ling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 24 of 33

ATTACHMENT 10.2 Page 10 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES ENCAPSULATING SUIT OR TURN-OUT GEAR (ES) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 62 NL NL NL 63 NL NL 240 64 NL NL 150 65 NL 240 120 66 NL 210 100 67 NL 165 90 68 NL 135 80 69 NL 110 70 70 240 95 65 71 230 85 55 72 215 80 50 73 200 70 45 74 180 65 40 75 165 55 40 76 150 50 35 77 130 50 35 78 115 45 30 79 110 40 25 80 100 40 25 81 90 35 20 82 85 35 20 83 75 35 20 84 65 30 20 85 60 30 15 86 55 25 PCR 87 50 25 PCR 88 50 25 PCR 89 45 25 PCR 90 40 20 PCR 91 35 20 PCR 92 30 20 PCR 93 30 20 PCR 94 25 20 PCR 95 25 15 PCR 96 25 15 PCR 97 25 PCR PCR 98 20 PCR PCR 99 20 PCR PCR 100 20 PCR PCR 101 20 PCR PCR 102 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2) rAP-020 Rev. 16 Page 25 of 33

ATTACHMENT 10.2 Page 11 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES FLAME RETARDANT SHIRT AND PANTS (FR)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 79 NL NL NL 80 NL NL 240 81 NL NL 150 82 NL 240 120 83 NL 210 100 84 NL 165 90 85 NL 135 80 86 NL 110 70 87 240 95 65 88 230 85 55 89 215 80 50 90 200 70 45 91 180 65 40 92 165 55 40 93 150 50 35 94 130 50 35 95 115 45 30 96 110 40 25 97 100 40 25 98 90 35 20 99 85 35 20 100 75 35 20 101 65 30 20 102 60 30 15 103 55 25 PCR 104 50 25 PCR 105 50 25 PCR 106 45 25 PCR 107 V

40 20 PCR 108 35 20 PCR 109 30 20 PCR 110 30 20 PCR 111 25 20 PCR 112 25 15 PCR 113 25 15 PCR 114 25 PCR PCR 115 20 PCR PCR 116 20 PCR PCR 117 20 PCR PCR 118 20 PCR PCR 119 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 26 of 33]

ATTACHMENT 10.3 Page 1 of 1 HEAT STRESS EVALUATION FORM JOB DATE:

JOB LOCATION:

TASK(S):

SUPERVISOR:

EST. PERSON-HOURS:

NUMBER OF WORKERS:

PLANT STATUS (for job planning use):

CLOTHING TYPE:

METABOLIC HEAT LOAD (CIRCLE ONE):

LIGHT MODERATE HEAVY TEMPERATURE (CIRCLE ONE):

MEASUREMENT ESTIMATE WBGT=

08= WB= GT=

ACTION TIME = minutes (from Attachment 10.2)

RECOVERY PERIOD = minutes = (Time in minutes in Hot Environment) x (60)

(Action Time in minutes)

HAVE WORKERS RECEIVED A PRE-JOB BRIEFING INCLUDING HEAT STRESS CONCERNS?

(CIRCLE ONE)

YES NO ADDITIONAL INFORMATION:

Signature (Job Supervisor): Date:

AP-020 Rev. 16 Page 27 of 33

ATTACHMENT 10.4 Page 1 of 1 ESTIMATING WBGT Measuring WBGT may require entering the work area prior to the start of the job.

However, this action could also create an ALARA conc ern.

There are two methods which can be used to estim ate the WBGT without entering the work area.

• The first method is to estimate the WBGT based on previously recorded measurements, such as those obtained from the Heat Stres s Evaluation Form (Attachment 10.3). The plant condition and work locat ion must be essentially identical to use this method.

NOTE: The following method may underestimate the actual WBG T for work performed directly adjacent to hot steam pipes or othe r radiant heat sources.

• The second method is based on a remote reading of the dry bulb temperature (DB) and an estimation of the relative humidity as follows:

(When the relative humidity is not known, use 100% value for estimation)

RELATIVE HUMIDITY ESTIMATED WBGT 100% DB+4°F 90% DB ÷ 2°F 80% DB 70% DB-3°F 60% DB-5°F 50% DB 7°F 40% DB 9°F AP-020 Rev. 16 Page 28 of 33

ATTACHMENT 10.5 Page 1 of 1 USING THE WET BULB GLOBE THERMOMETER Measuring WBGT by using the Wet Bulb Globe thermome ter will require entering the work area prior to the start of the job. Be sure to prepare the meter for use, prior to bringing it into the hot environment, in order to save time.

To prepare the meter:

1. Connect each of the wet bulb, dry bulb, and globe sens ors to the unit. Look at the symbols located on the top of the unit to determine the appropriate connector for each sensor. Use caution to insure that the connector prongs are aligned properly in order to avoid damaging the sens ors.

2. Use distilled water to saturate the sponge and wick on the wet bulb sensor.

To operate the meter:

1. Turn the meter on to the desired function; WBGT in for indoor measurements, or WBGT out for outdoor measurements.

2. Allow the sensors to stabilize in the environment wher e reading is being taken. Typical response times may be as long as 15 minute s.

3. Take reading once display has stabilized.

Changing Batteries/Meter Calibration:

1. Consult owners manual.

AP-020 Rev. 16 Page 29 of 33

ATTACHMENT 10.6 Page lot 1 HEAT STRESS PRE-JOB BRIEFING Advise persons entering a heat stress area of the recommended action time and the absolute stay time.

Advise persons entering a heat stress area of any required engineering controls or of any personal cooling device requirements, such as ice vests or Tube Suits.

Advise persons entering a heat stress area:

• They may become dehydrated due to sweating.

• Lost body water and electrolytes should be replaced by drinking during rest breaks to prevent heat-related illness.

• Where they may obtain drinking water and/or Gatorade.

• Where cooler rest areas are located and the duration of minimum recovery times.

First Aid for Heat Stress:

Heat Cramps are muscle spasms due to a loss of salt through sweating. Leg, stomach, and back muscles are most often affected and are often a sign of approaching heat exhaustion. Cramps can also result from drinking large amounts of water without electrolytes (salt, sugar).

First Aid: Rest in cool area, drink water or Gatorade, and eat food high in salt content.

Heat Exhaustion Condition caused by an insufficient flow of blood to the brain (blood is shunted to the skin to lose heat). Symptoms can include cool, pale clammy skin, weakness, dizziness, headache, nausea, and fainting.

First Aid: Rest in cool area, lie down, elevate feet, apply cool wet cloths, fan with air, and drink liquids.

Heat Stroke a serious medical emergency caused by a failure of the bodys cooling mechanisms. Symptoms include hot, dry skin (sweating stops), extremely high body temperatures, strong, rapid pulse, and unconsciousness.

First Aid: Immediate, rapid cooling of the body is necessary. Use safety showers, move air over the body with a fan or by fanning, or cover the body with a wet sheet.

Seek immediate medical attention.

AP-020 Rev. 16 Page 30 of 33

ATTACHMENT 10.7 Page 1 of 3 DEFINITIONS

• Absolute Stay Time Two times the Recommended Action Time (lAW Attachment 10.2 and EPRI guidelines)

• Acclimation The gradual process of improved heat tolerance after continuous exposure to heat. Acclimation consists of reduced heart rate, increased sweat production, production of less salty sweat, and lower body temperature.

• Action Time An estimate of the length of time worker s may be exposed in hot environments without personal cooling devices and not suffer heat stress disorders (used for planning purposes). The length of action times is not absolute because of worker variability in response to heat.

• ALARA (As Low As Reasonably Achievable) Making every

- reasonable effort to maintain exposure to radiation as far below the dose limits as is practical, taking into account the state of technology, and the economics of improvements in relation to the benefits.

• Cloth Coveralls (CC) A standard configuration of anticontamina tion coveralls with a hood and hand and foot coverings. The fabric is either a cotton or cotton/polyester blend with weights of about 8 to 9 oz/sqyd.

• Cloth Coveralls over Scrub Suit (CS) The configuration desc ribed as CC plus a set of 2 oz/sqyd cloth underalls (a.k.a. surgical scrub suit).

• Double Cloth Coveralls (DC) The configuration described as CC plus a second set of cloth coveralls only.

• Dry Bulb Temperature (DB) The temperature as meas ured by a standard thermometer, without respect to humidity or radiant heat.

• Encapsulating Suit or Turn-out Gear (ES) Total encapsul ating suits (eg, Level A); re-usable, whole body chemical protective suits; firefighter turn-out gear.

• Flame-Retardant Shirt and Pants (FR) Long-sleeve shirt and pants made from a treated cotton fabric.

• Globe Temperature (GT) Temperature resulting from radiant heat sources, measured with a globe thermometer.

• Globe Thermometer A thermometer with a black globe at its end, used for measuring radiant heat.

AP-020 Rev. 16 Page 31 of 33

ATTACHMENT 10.7 Page 2 of 3 DEFINITIONS (Continued)

• Heat Stress The physiological stress which occurs when the body temperature rises above normal. This occurs when the body produces or gains more heat than it is capable of losing. It is caused by any combination of air temperature, thermal radiation, humidity, air flow, restrictive clothing, and physical work load which may result in elevated core body temperature and subsequent illness.

• High Heat Stress Job/Work Any job or work in which the calculated action time, without regard to personal cooling equipment, is less than 30 minutes.

• MB Polyethylene Coveralls (PE) Limited use coveralls with hood (particle barrier only) made from a meltblown polyethylene (Tyvek 1422A).

• Metabolic Heat Load Heat generated by the body, which increases with physical work. Examples may be found on Attachment 10.1.

• Moderate Heat Stress Job/Work Any job/work in which the calculated action time, without regard to personal cooling equipment, is greater than 30 minutes but less than 240 minutes.

• OREX Disposable coveralls made of poly vinyl alcohol (PVA).

• Personal Cooling Device Equipment such as ice vests or Tube Suits, used to minimize heat gain and/or increase heat loss.

• Polyester Coveralls (P2) Light-weight polyester (98% nylon)(3 oz/sqyd) coveralls worn with a hood of the same material (ProTech 2000).

• Polyester Coveralls with Scrubs (PS) Light-weight polyester coveralls and hood (P2) worn over a typical surgical scrub suit (cotton or cotton/polyester blend).

• Protective Clothing Items worn to prevent radioactive contamination.

• Recovery Period Time allowed to be spent outside of a hot area allocated to workers who have performed work in hot environments. Water or gatorade should be available for consumption in the recovery area.

• Relative Humidity The amount of moisture in the air compared to the amount of moisture the air can hold for a given temperature.

• Self Determination Allowing for worker discretion to exit Heat Stress Work Areas.

AP-020 Rev. 16 Page 32 of 33

ATTACHMENT 10.7 Page 3 of 3 DEFINITIONS (Continued)

• SMS Polypropylene Coveralls (PP) Limited-use coveralls with hood (particle barrier only) made from a spunbonded, meltblown polypropylene.

• Supplied Air Hood Air-supplied hood respirator which will deliver respirable air over the head and upper body.

• Vapor-Barrier Coveralls (VB) Coveralls and hood made of light weight fabrics designed for limited use. Typical fabrics might be a polyethylene coated spunbonded polyethylene or a polyvinylchloride.

• Water-Barrier, Vapor Permeable Coveralls (WB-1) Limited-use coverall with hood made from tn-laminate fabric with a tetrafluoroethylene microporous film.

• Water-Barrier, Vapor Permeable Coveralls (WB-2) Coverall with hood made from tn-laminate fabric with a microporous film.

• Wet-Bulb Temperature (WB) The temperature as determined by a wet bulb thermometer. This temperature is influenced by the evaporation rate of water, which is dependent upon the relative humidity in air.

• Wet-Bulb Globe Temperature (WBGT) An index of heat-stress based on globe, dry and wet bulb temperatures.

• Wet-Bulb Globe Thermometer A thermometer with sensors to measure wet bulb, dry bulb, and globe temperatures.

• Work Clothes (WC) A standard ensemble that includes a 4 ozlsqyd cotton shirt with long sleeves and 8 oz/sqyd cotton pants.

AP-020 Rev. 16 Page 33 of 33

AA S tt 1 /

ATTACHMENT 10.3 Page 1 of 1 HEAT STRESS EVALUATION FORM JOB DATE:

JOB LOCATION: At 7/ h//eq TASK(S):

V4

. LJ A

SUPERVISOR: /.

EST. PERSON-HOURS: 1<0 NUMBER OF WORKERS: 2-PLANT STATUS (for job planning use): /Wobt \3 CLOTHING TYPE:

(2,-K (Wi //

METABOLIC HEAT LOAD (CIRCLE ON --------.

LIGHT MODERATE HEAVY TEMPERATURE (CIRCLE ONE):

MEASUREMENT WBGT=

GT =

ACflON TIME = mThues (from 10.2)

RECOVERY PERIOD 7 3 f minutes = (Time in minutes in Hot Environment) x (60)

(Action Time in minutes)

HAVE WORKERS RECEIVED A PRE-JOB BRIEFING INCLUDING HEAT STRESS CONCERNS

?

(C ONE)

YES NO DITIONAL INFORMATION:

Signature (Job Supervisor): < J7(flk_1Date: 1 L i,fr/

AP-020 Rev. 16 Page 27 of 33

41 Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: HB ROBINSON Task No.: 02344101203 Task

Title:

Complete Equipment Inoperable JPM No.: 2011-2 NRC JPM Admin Record SRO A1-2 K/A

Reference:

G2.1 18 (3.61 3.8)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

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

Initial Conditions:

• Unit operating at 100% RTP steady state

• CCW Pump B removed from service at 1245 hours0.0144 days <br />0.346 hours <br />0.00206 weeks <br />4.737225e-4 months <br /> on 12/1/11 due to failed inboard motor bearing

• No additional equipment is inoperable

• Current plans will return to service in 44 hours5.092593e-4 days <br />0.0122 hours <br />7.275132e-5 weeks <br />1.6742e-5 months <br />

• Work order # 47548629 has been initiated

• NCR # 407627 has been initiated Task Standard: Complete OMM-007, Attachment 10.1 and 10.11 Required Materials: OMM-007, Equipment Inoperable Record, Rev. 84 PLP-100, Technical Requirements Manual, Rev. 36 General

References:

OMM-007, Equipment Inoperable Record, Rev. 84 Handouts: OMM-007, Equipment Inoperable Record, Rev. 84 PLP-100, Technical Requirements Manual, Rev. 36 2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Initiating Cue: The CRS has directed you to complete the necessary OMM

-007 attachment(s) for the inoperability of CCW Pump B Another SRO will perform the checklist of OMM-OOi-8, Control of Equipment and System Status and OPS-NGGC-i 000, Fleet Conduct of Operations.

All necessary outside notifications will be made by the Shift Manager.

Time Critical Task: NO Validation Time: 30 minutes 2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 15 Form ES-C-I PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk Start Time:

NOTE: Completion of EIR Ultimate Heat Sink (UHS) for Service Water Temperature Exceeding 97°F will be used versus this section if entering ITS LCO 3.7.8 (UHS) REQUIRED ACTIONS due to Service Water temperature exceeding 97°F.

Performance Step: I Perform the Revision Verification (Step 8.2.1)

Standard: Candidate performs the revision verification or states that he uses the Control Room copy, enters todays date and initials on Attachment 10.1, EIR ITS/TRM/ODCM/RG 1.97.

Examiners Note:

Examiners Cue: Revision verification is the correct revision.

Comment:

Performance Step: 2 Enter the name of the equipment which is inoperable in Section A (Step 8.2.2)

Standard: Candidate enters CCW Pump B in Section A.

Examiners Note:

Comment:

2011-2 NRC JPM Admin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 3 Record the reason for the equipment inoperability. This may include MOD number, problems with the equipment, and/or work to be performed (Step 8.2.3)

Standard: Candidate documents that motor bearing failure is the reason for the inoperability.

Examiners Note:

Comment:

Performance Step: 4 Verify a Work Request has been initiated (if applicable) AND record the WR number (ACR 94-00281) (Step 8.2.4)

Standard: Candidate documents a work request number and fills in the WR

1. blank.

Examiners Note:

Comment:

2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 15 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 5 IF the unavailability is unplanned, AND the component is part of a system listed on Attachment 10.10, THEN review OMM-048 AND the Maintenance Rule Scoping and Performance Criteri a

basis section of the Maintenance Rule Database to determine if the listed function(s) of the system is/are affected.

IF a system function is affected, THEN initiate a CR stating a

potential Safety Significant Functional Failure has occurred lAW OMM-048, and record the CR# in Section D (Step 8.2.5)

Standard: Candidate determines that the unavailability is unplanned and the component is listed in Attachment 10.10. A CR number is recorded in the blank under Section D.

Examiners Note: Attachment 10.10, Maintenance Rule Systems, lists System

1. 4080, ComponentlCooling Water System to be considere d

a High Safety Significant System under the Maintenance Rule.

Comment:

Performance Step: 6 Complete Section E as follows:

Item 1 Enter the TIME AND DATE that the equipment was declared inoperable (Step 8.2.6)

Standard: Candidate enters the TIME as 1245 and DATE as 1211/11.

Examiners Note:

Comment:

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 15 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 7 Complete Section E as follows:

Item 2 Circle the applicable document abbreviation and enter applicable LCO, TRMS or Specification number. Be specific. For example, provide table number and item number where applicable.(Step 8.2.6)

Standard: Candidate circles ITS and enters LCO 3.7.6, Condition A.

Examiners Note:

Comment:

• Performance Step: 8 Complete Section E as follows:

Item 3 Enter any applicable actions required to satisfy the document identified in Item 2 and any required completion time. (Step 8.2.6)

Standard: Candidate enters as follows: Restore required CCW Train to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. THEN apply Condition B Be in Mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

Examiners Note:

Comment:

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 15 Form ES-C-I PERFORMANCE INFORMATION

• Performance Step: 9 Complete Section E as follows:

Item 4 Enter the maximum time the equipment is allowed to be inoperable in the applicable blank. Circle hrs/days as they apply to the Special Report. (Step 8.2.6)

Standard: Candidate enters 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> in the MODE 3 blank and 108 hours0.00125 days <br />0.03 hours <br />1.785714e-4 weeks <br />4.1094e-5 months <br /> in the MODE 5 blank.

Examiners Note:

Comment:

• Performance Step: 10 Complete Section E as follows:

Item 5 Enter the Time and Date that ltem4 is required in the applicable blank. (Step 8.2.6)

Standard: Candidate enters 1845 in the Time blank and 1214111 in the Date blank for MODE 3.

Candidate enters 0045 in the Time blank and 1216111 in the Date blank for MODE 5.

Examiners Note:

Comment:

NOTE: ODCM required initial compensatory samples lack a grace period.

2011-2 NRC JPMAdmIn SROAI-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 11 Complete Section E as follows:

Item 6 Enter any applicable surveillances or activities and required frequencies which are required as a result of the component inoperability. (Step 8.2.6)

Standard: Candidate enters NONE.

Examiners Note:

Comment:

2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 12 IF the component is an ITS Support System component, THEN perform Attachment 10.11, which is provided to ensure Safety Function Determinations are performed consistently. The TRM contains in-depth guidance for performing Safety Function Determinations. [CAPR 193057] (Step 8.2.7) (Attachment 10.1, Section F)

Standard: Candidate determines the following from Attachment 10.11, Loss of Safety Function Worksheet, Page 1 of 4:

1. TS Support Feature is Inoperable Yes, CCW Pump B.

2. Determine the impact the inoperability has on applicable supported systems.

3. Does the TS support feature result in a supported feature LCO not met NO

4. Exit the SFDP.

Attachment 10.11, Page 2 of 4 completed as follows:

Revision status checked with Date and INIT filled in.

Date of 1211111 and Time of 1245 completed MODE 1, Power 100%, RCS Temperature - 575.9°F, RCS Pressure 2235 psig.

1) List inoperable ITS Support Feature: CCW Pump B listed and step initiated.

2) IF inoperable ITS Support Feature does NOT result in ITS Supported Feature inoperability, THEN perform the following:

a) N/A Steps 3 through 8 and step initialed.

b) Sign and Date and step initialed.

Examiners Note:

Comment:

2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 13 IF the component is an ITS Supported System Component, THEN review open Loss of Safety Function Worksheets (Attachment 10.11) for impact AND log in AUTO log to document review. [CAPR 193057] (Step 8.2.8) (Attachment 10.1, Section G)

Standard: Candidate determines that there are no open Loss of Safety Function worksheets.

Examiners Note:

Comment:

Performance Step: 14 Initial the blank in Section H when the Load Dispatcher has been notified when the component inoperability could force plant shutdown or load reduction. [SOER 99-i. Rec. IC] (Step 8.2.9)

Standard: Candidate initials blank for Load Dispatcher notification.

Examiners Cue: If requested, respond as the Load Dispatcher that notification has been received.

Comment:

Performance Step: 15 Initial the blank in Section I when Planning and Scheduling has been notified when ITS/TRM/ODCM/RG 1.97 actions have been entered and plant shutdown is anticipated. (Step 8.2.10)

Standard: Candidate initials the blank that Planning and Scheduling has been notified of anticipated plant shutdown.

Examiners Cue: If requested, respond as Planning and Scheduling that notification has been received.

Comment:

2011-2 NRC JPM Admin SRO Al -2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 1 1 of 15 Form ES-C-I PERFORMANCE INFORMATION Performance Step: 16 IF the EIR is completed due to a Radiation Monitor, Flowrate Monitor or Tank Level Monitor inoperability, THEN enter the E&C Technicians name, time and date of notification in the blanks in Section J. (Step 8.2.11)

Standard: Candidate determines that the component inoperability does not involve any radiation monitor, flowrate monitor or tank level monitor and N/As the blanks in Section J of Attachment 10.1.

Examiners Note:

Comment:

NOTE: Maintenance Rule data can be found by clicking on Start, Programs, Engineering, RNP, and RNP System Notebook. When the database opens move the desired system(s) from the list of available systems to the list of selected systems. From the list of Systems Notebook links click on M.R. System Specific Reports, then click on Performance Summary.

• Performance Step: 17 IF a Maintenance Rule System monitored for unavailability (Attachment 10.10, page 2) is affected, THEN record the Allowed Unavailability hours, subtract the actual unavailability hours, and record the remaining unavailability hours in Section K. (NCR 102997) (Step 8.2.12)

Standard: Candidate determines that System 4080-CCW, CCW Pump Trains is listed in Attachment 10.10, Page 2. ,. V /

Candidate determines that the Allowed Unavailability hours is 132 hours0.00153 days <br />0.0367 hours <br />2.18254e-4 weeks <br />5.0226e-5 months <br />, the actual unavailability hours is 94.25 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br /> and the \\

remaining unavailability hours is 38 hours4.398148e-4 days <br />0.0106 hours <br />6.283069e-5 weeks <br />1.4459e-5 months <br />.

132 Hours Allowed 94.25 Hours Actual = 38 Hours Remaining will be entered in Section K of Attachment 10.1.

Data will be provided to the candidate from the Maintenance Examiner s Note:

Rule Database.

Comment:

2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 12 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 18 IF the unavailability is unplanned and remaining unavailability hours are less the 72, THEN notify the RES Duty Manager and record the name, date, and time in Section K. (NCR 102997)

(Step 8.2.13)

Standard: Candidate determines that the remaining hours is less than 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> and notifies the RES Duty Manager. He documents the name, date and time that the notification was made.

Examiners Note:

Comment:

Performance Step: 19 The SM OR the CRS shall review the EIR AND sign AND date following completion in Section L. (Step 8.2.14)

Standard: Candidate will sign and date the Completed By portion of Attachment 10.1, Section L.

Examiners Note:

Comment:

Performance Step: 20 The comments section is used for documenting failed testing or changed equipment status. (Step 8.2.15)

Standard: Candidate can place any comments needed or mark the comments as N/A or NONE.

Examiners Note:

Comment:

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

Appendix C Page 13 of 15 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Termination Cue: EIR completion for the CCW Pump B inoperability completes the JPM.

STOP TIME:

2011-2 NRC JPM Admin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 14 of 15 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM Admin SRO A1-2 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 Admin SROA1-2 NUREG 1021, Revision 9, Supplement 1

11Ah,i Y ATTACHMENT 10.1 Page 1 of 2 EIR ITSITRM!ODCM/RG 1.97 CONTINUOUS USE This revision has been verified to be the latest revision available.

Date( INIT A. Equipment Inoperable: cJ&)

B. Reason for Equipment Inoperability: / ,j7(r? i, Mi-(

4

/&) A1?7k /4/f C. WR initiated: (ACR 94-00281) WR # 41 7 D. IF an unplanned unavailability AND a High Safety Significant Maintenance Rule System FUNCTION is affected by the equipment, THEN initiate CR stating a potential sety significant functional failure has occurred. CR # t1.2 F. Operating Limitations:

1. Equipment declared inoperable: Time (z$6 Date /2_/( /( /

2. ITS RM/ODCM/RG 1 .97Other reference number Circle one) 1/If /

4Jd/ 77/ 14 1

O

3. Qther actions aj associated cmpIetion tim:/ A Ct) fl,jij)

-I- A (ec-4fzs /,M,s) 7- .AG1/4. 7MJ 4/(

1 .Mc iA 6 &i ,1 J fcA)

4. aximum time equipment awed inopera e be ore:

MODE 2 Hrs MODE 3 Hrs MODE 4 Hrs MODE 5-lrs /t1Uf Special Report hrs/days

5. Time AND Date Action Required:

MODE 2 Time: Date:

MODE 3 Time: Date: /a,/yyif MODE 4 Time: Date:

MODE 5 Time:OI Date:

Special Report Time: Date:

6. Record any surveillance required to be performed as a result of the inoperability of this compopent CODCM initial compensatory samples lack a grace period.)

IAlF OMM-007 Rev. 85 Page 31 of 88

ATTACHMENT 10.1 Page 2 of 2 EIR ITSITRMIODCM!RG 1.97 F. IF this is an ITS Support System Component, THEN perform Attachment 10.11.

[CAPR 193057]

G. IF this is an ITS Supported System Component, THEN review open Loss of Safety Function Worksheets (Attachment 10.11) for impact.

H. Load Dispatcher$j9f1 of REQUIRED ACTION which could force plant shutdown/load reduction. J/j-i (SM/CRS Initials) [SOER 99-1, Rec. 1C]

Planning and Scheduling notified to develop Forced Outage Schedule if lTS/4OjCM/RG 1.97 actions are entered AND plant shutdown anticipated.

<47L (SM/CRS Initials)

J. IF this EIR is for a Radiation Monitor, Flowrate Monitor or Tank Level Monitor, THEN notify E&C of equipme t inoperability:

9 Time /)/,4 Date_______

E&C Shift Technician (Print name)

K. IF a Maintenance Rule System Function is affected, THEN record Allowed Unavailability Hours, Actual Unavailability Hours, and Unavailability Hours Remaining.

/3ZHours Allowed -Q4(f Hours Actual = c4.,Hours Remaining IF unpl ned and less than 72 Hours remaining THEN notify the RES Duty Manager.

,)

Name A)5 3

L (zI

(/11 / Ic at Time L. Completed By: / u/i/i /

SM/CRS Dte M. Comments:

N. Restoration

1. Equipment operable: Time Date

2. IF this EIR is for a Radiation Monitor, Flowrate Monitor or Tank Level Monitor, THEN notify E&C of equipment return to service:

Time Date E&C Shift Technician (Print Name)

3. Equipment no longer required due to plant conditions:

Time Date Reason:

4. Completed By:

SM/CRS Date OMM-007 Rev. 85 Page 32 of 88

ATTACHMENT 10.10 Page 1 of 2 MAINTENANCE RULE SYSTEMS INFORMATION USE The following systems are considered to be High Safety Significant Systems under the Maintenance rule.

1000 Containment Isol Valve Pseudo 5098 Dedicated Shutdown Diesel Generator System 1005 Reactor Vessel and Internals System 5100 Fuel Oil System 1045 Excore Nuclear Instrument System 5114 Dedicated Shutdown System 1065 Rod Control System 5120 Switchyard and Transformer System 1080 Reactor Protection and Safeguards 5170 4 Ky AC Distribution System System 2005 Reactor Coolant System 5175 480V AC Distribution System 2045 Residual Heat Removal System 5185 208-120 VAC Distribution System 2060 Chemical and Volume Control System 5235 125V DC Battery/Charger/Distribution System 2080 Safety Injection System 6135 Instrument Air System 3005 Steam Generator 6150 Nitrogen Supply/Blanketing System 3020 Main Steam 6175 Site Fire Protection System 3050 Feedwater System 6270 Primary and Demineralized Water Makeup System 3065 Auxiliary Feedwater 8010 Containment System 3070 Condensate System 8150 HVAC Containment Building System 4060 Service Water System 8210 HVAC Auxiliary Building 4080 ComponentCooHng WatE2 8220 HVAC Control Room Area 5095 Emergency Diesel Generator System OMM-007 Rev. 85 Page 55 of 88

ATTACHMENT 10.10 Page 2 of 2 MAINTENANCE RULE SYSTEMS The following systems require unavailability monitoring for the maintenance rule:

System Whats Monitored 1065 Rod Drive Reactor trip breakers 2005 RCS RCS PORVs and block valves 2045 RHR RHR trains 2060 CVCS Charging pump trains, boric acid pumps, emergency boration ftowpath 2080 SI SI Pump trains, CV Spray trains, Accumulators 3020 MS S/G PORVs, Steam Supplies to SDAFW 3065 AFW AFW Pump trains, injection lines 4060 SW SW pumps, SW booster pumps, north and south headers, Turbine B uild hig Isolation C 4080 i pump trainheat exchangers 5095 EDG EDG trains 5098 DSDG Dedicated Shutdown Diesel 5114 DS DS bus, DS-UPS-Inverter 5170 4 Ky Auto Bus Transfer breakers 5175480 V Bus E-1, Bus E-2 5185 120 / 208 VAC Constant voltage transformers 5235 125 VDC Battery Chargers, Inverters, DC Buses 6004 ERFIS ERFIS Computer 6135 IA Compressors, Backup Air Supply For Charging Pumps 6175 FP Pumps, Flowpath to SI, AFW, CVCS Pump cooling / suction 6270 Primary Water Deep Well Pump D, Primary Water Pumps and Header 8150 CV HVAC HVH units 8220 MCR HVAC Ventilation fans, Emergency Filtration Unit, Control Room Envelope Integrity OMM-007 Rev. 85 Page 56 of 88

ATTACHMENT 10.11 Page 1 of4 LOSS OF SAFETY FUNCTION WORKSHEET

[CAPR 193057]

CONTINUOUS USE in NOTE: The numbers in the flow chart correspond to the description of SFD steps Appendix C of the TRM.

Page 57 of 88 f OMM-007 Rev. 85

ATTACHMENT 10.11 Page 2 of 4 LOSS OF SAFETY FUNCTION WORKSHEET This revision has been verified to be the latest revision available.

Date: /2_/(((( Plant Conditions Time:__________

MODE Power RCS Temperature RCS Pressure

/ (CO  % F zz NOTE: This Safety Function Determination should be performed by a licensed Senior Reactor Operator and should be reviewed any time additional inoperabilities occur or an ITS Supported Feature is declared inoperable.

1) List inoperable ITS Support Featur

/CL) /i&

2) IF inoperable ITS Support Feature does NOT result in ITS Supported Feature inoperability, THEN perform the following:

a) N/A steps 3 through 8.

b) Sign and date.

c) Forward worksheet to SM for review.

d) IF the Support Feature will NOT be returned to service prior to end of shift, THEN attach completed worksheet to the EIR for the Support Feature.

e) IF the Support Feature will be returned to service prior to end of shift, THEN file LOSF Worksheet in EIR notebook.

3) IF inoperable ITS Support Feature results in ITS Supported Feature inoperability, THEN list inoperable ITS S p orted Feature(s).

OMM-007 Rev. 85 Page 58 of 88

ATTACHMENT 10.11 Page 3 of 4 LOSS OF SAFETY FUNCTION WORKSHEET IN IT Actions,

4) IF support feature ITS Actions require cascading to Supported Feature(s) ITS THEN perform the following; a) Enter applicable ITS Actions of Supported Feature(s) ITS.

b) N/A steps 5 through 8.

c) Sign and date.

d) Forward worksheet to SM for review.

e) Attach completed worksheet to the EIR for the Support Feature.

abilities

5) IF any other ITS LCOs are NOT met, THEN determine the impact the inoper have on all applicable 7 Su y eatu or res t AND list.

the following;

6) IF there are NO redundant Supported Features inoperable, THEN perform a) N/A steps 7 and 8.

b) Sign and date. A4LA c) Forward worksheet to SM for review.

d) Attach completed worksheet to the EIR for the Supported Feature. lU/A the following:

7) IF a LOSF does NOT exist for the Supported Feature ITS, THEN perform Support a) Calculate and record the maximum completion time to restore the ITS Feature nji associated ITS Supportecj, Featur e(s) to operab le tatus.

1st Support Feature Supported Feature Max Completion b) N/Astep8.

c) Sign and date.

,iJ44 A)44 d) Forward worksheet to SM for review.

e) Attach completed worksheet to the EIR for the Supported Feature.

Al/A OMM-007 Rev. 85 Page 59 of 88

ATTACHMENT 10.11 Page 4 of 4 LOSS OF SAFETY FUNCTION WORKSHEET INIT following:

8) IF a LOSF exists for the Supported Feature ITS, THEN perform the a) Calculate and record the maximum completion time to restore the ITS Support /1 Feature n associated ITS Support d Featur e(s) to operab i status. ALjft IJ)k h rs + 16174 1St Suppo Feature Supported Feature Max Completion LCO 3.0.3 as b) Enter the applicable ITS LCO for the ITS Supported Feature or ITS applicable.

e.

c) Attach completed worksheet to the EIR for the Supported Featur Remarks:

/4 Completed By: Date: /z/( (If SRO Reviewed By: Date:

SM Page 60 of 88 j OMM-007 Rev. 85

.7 0

RNP Maintenance Rule Event List System 4080 Monitoring Event Date End Date EVENT UNAVAILABLE HOURS 5.53 CCW Pump Train A 7129/2010 7/29/2010 CCW-PMP-A-MTR TAKEN DOS TO LUBRICATE MOTOR BEARI 7.10 CCW Pump Train A UNAVAILABLE HOURS 8/25/2010 8/25/2010 CCW-PMP-A Taken OOS for oil sample 4.01 CCW Pump Train A UNAVAILABLE HOURS 1/14/2011 1/14/2011 CCW-PMP-A taken DOS for oil sample 7.81 CCW Pump Train A UNAVAILABLE HOURS 5/31/2011 CCW-PMP-A taken DOS for oil and oiler change 5/31/2011 UNAVAILABLE HOURS 4.11 d mainte nance CCW Pump Train A 8/25/2011 8/25/2011 CCW-PMP-A DOS for planne 53.06 CCW Pump Train A UNAVAILABLE HOURS 9/1212011 9/14/2011 CCW-PMP-A unavailable due to OS bus outage 81.62 UNAVAILABLE HOURS 7.75 CCW Pump Train B 7/27/2010 7/27/2010 CCW-PMP-B TAKEN DOS TO LUBRICATE MOTOR BEARINGS 2.73 CCW Pump Train B UNAVAILABLE HOURS 8/24/2010 8/24/2010 CCW-PMP-B Taken DOS for oil sample UNAVAILABLE HOURS 45.68 CCW Pump Train B 9/29/2010 10/1 /20 10 CCW-PMP-B Taken DOS to remove foreign material UNAVAILABLE HOURS 3.88 CCW Pump Train B 1/14/2011 1/14/2011 CCW-PMP-B taken DOS for oil sample UNAVAILABLE HOURS 5.66 CCW Pump Train B 1/22/2011 1/22/2011 CCW-PMP-B taken DOS for oil sample UNAVAILABLE HOURS 3.20 CCW Pump Train B 1/23/2011 1/23/2011 CCW-PMP-B taken DOS for oil sample, follow-up UNAVAILABLE HOURS 3.10 CCW Pump Train B 2/12/2011 2/12/2011 CCW-PMP-B DOS for Oil Sample UNAVAILABLE HOURS 10.50 CCW Pump Train B 3/8/2011 3/8/2011 CCW-PMP-B DOS for OB bearing replacement UNAVAILABLE HOURS 2.63 CCW Pump Train B 3/9/2011 3/9/2011 CCW-PMP-B DOS for oil sample UNAVAILABLE HOURS 2.53 CCW Pump Train B 5/1 3/2011 5113/2011 CCW-PMP-8 taken DOS for oil flush and sample UNAVAILABLE HOURS 3.48 CCW Pump Train B 6/3/2011 6/3/2011 CCW-PMP-B taken DOS for oil change and sample UNAVAILABLE HOURS 3.11 CCW Pump Train B 8/25/2011 8/25/2011 CCW-PMP-B DOS for planned maintenance 94.25 UNAVAILABLE HOURS 6.41 r inspections CCW Pump Train C 8/11/2010 8/11/2010 CCW-PMP-C taken DOS for oil sample and breake UNAVAILABLE HOURS 33.41 to replace pump seals CCW Pump Train C 9/12/2010 9/13/2010 CCW-PMP-C taken DOS UNAVAILABLE HOURS 38.66 repair CCW Pump Train C 4/5/2011 4/7/2011 CCW-PMP-C taken DOS for seal leak, sleeve nut UNAVAILABLE HOURS 3.73 DOS for oil sample CCW Pump Train C 4129/2011 4/29/2011 CCW-PMP-C taken UNAVAILABLE HOURS 19.13 leakage CCW Pump Train C 6/1412011 6/15/2011 CCW-PMP-C taken DOS, measurements for seal UNAVAILABLE HOURS 2.96 CCW Pump Train C 8/1 5/2011 8/15/2011 CCW-PMP-C DOS for planned maintenance Page 1 10/13/20 11

0 Event Title Monitoring Event Date End Date 104.30

- CCW Pump Train C 5/7/2010 ONLINE GEMCO SWITCH REFURBISHMENT 1/CCW-C-MTR 10129/2010 CCWPMP-C OOS to repair seal leak CCW Pump Train C System Integrity and Cooling Flowpath 5/22/2010 CC-862F MAYBE CLOGGED System Integrity and Cooling Flowpath 5/29/2010 IMPLEMENT EC 63452 FOR CC-749A (CHILD EC 69284)

System Integrity and Cooling Flowpath 6/30/2010 FIC-629 ON ERFIS INDICATES FLOW LO System Integrity and Cooling Flowpath 4/14/2011 MCC-5(3M)-42/C; ESTABLISH PICKUP/DROPOUT VOLTAGES Page 2 10/13/2011

RNP Maintenance Rule Monitoring Status 4080 Component/Cooling Water System

• .1fiV!j i1r TitIe -1im Type 132 0 132 4/11/2010 UNAVAILABILITY UNAVAILABLE HOURS 1 10/13/2008 1 0 RELIABILITY FUNCTIONAL FAILURES

. 188 81.62 106 4/11/2010 UNAVAILABILITY UNAVAILABLE HOURS 10/13/2008 1 0 1 4 RELIABILITY FUNCTIONAL FAILURES 132 94.25 38 4/11/2010 UNAVAILABILITY UNAVAILABLE HOURS 1 10/13/2008 1 0 RELIABILITY FUNCTIONAL FAILURES qStatusA2 i___

• .[e CCW Pump TrainQ 132 104.3 28 4/11/2010 UNAVAILABILITY UNAVAILABLE HOURS 10/13/2008 1 0 1 J RELIABILITY FUNCTIONAL FAILURES 2 0 2 10/13/2008 RELIABILITY FUNCTIONAL FAILURES 0 0 0 10/13/2008 RELIABILITY FUNCTIONAL FAILURES 1 0 1 10/13/2008 RELIABILITY FUNCTIONAL FAILURES Page 1 10/13/2011

RNP MR PMG Monitoring Trend 4080 Component/Cooling Water System r PMG:

Monitoring:

CCW Pump Train A UNAVAILABLE HOURS N

Monitoring period (days):

Allowable:

Actual:

550 188 81.62 Goal:

60 50 40 30 20 I

I I I I I I I I I%% ..

. F ,f I Monitoring period (clays): 550 PMG: CCW Pump Train B Allowable: 132 Monitoring: UNAVAILABLE HOURS Actual: 94.25 Goal: N 50 45 40 35 30 25 20 15 10 S

0 I%

I / 1 Page 1 10/13/2011

RNP MR PMG Monitoring Trend 4080 Component/Cooling Water System Monitoring period (days): 550 PMG: CCW Pump Train C Allowable: 132 Monitoring: UNAVAILABLE HOURS Actual: 104.3 Goal: N 45, 40 35 p%P*. %

S ,

, i Page 2 10/13/2011

Appendix C Page 15 of 15 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• Unit operating at 100% RTP

• CCW Pump B removed from service at 1245 hours0.0144 days <br />0.346 hours <br />0.00206 weeks <br />4.737225e-4 months <br /> on 12/1/11 due to failed inboard motor bearing

• No additional equipment is inoperable

• Current plans will return to service in 44 hours5.092593e-4 days <br />0.0122 hours <br />7.275132e-5 weeks <br />1.6742e-5 months <br />

• Work order # 47548629 has been initiated

• NCR # 407627 has been initiated INITIATING CUE: The CRS has directed you to complete the necessary OMM-007 attachment(s) for the inoperability of CCW Pump B Another SRO will perform the checklist of OMM-001-8, Control of Equipment and System Status and OPS-NGGC-i 000, Fleet Conduct of Operations.

All necessary outside notifications will be made by the Shift Manager.

2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 15 of 15 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• Unit operating at 100% RTP

• CCW Pump B removed from service at 1245 hours0.0144 days <br />0.346 hours <br />0.00206 weeks <br />4.737225e-4 months <br /> on 12/1/11 due to failed inboard motor bearing

• No additional equipment is inoperable

• Current plans will return to service in 44 hours5.092593e-4 days <br />0.0122 hours <br />7.275132e-5 weeks <br />1.6742e-5 months <br />

• Work order # 47548629 has been initiated INITIATING CUE: The CRS has directed you to complete the necessary OMM-007 attachment(s) for the inoperability of CCW Pump B Another SRO will perform the checklist of OMM-001-8, Control of Equipment and System Status and OPS-NGGC-1 000, Fleet Conduct of Operations.

All necessary outside notifications will be made by the Shift Manager.

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

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

Perform Section 8.2.3 of OST-020, JPM No.: 2011-2 NRC JPM SRO Task

Title:

Shiftly Surveillances A2 K/A

Reference:

G2.2.37 3.6 / 4.6 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testincj:

Simulated Performance: X Actual Performance:

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

Initial Conditions: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

Task Standard: Identify all out of specification readings and apply all applicable Technical Specification requirements.

Required Materials: OST-020 ITS General

References:

OST-020 Shiftly Surveillances, Revision 41 Handouts: OST-020 Initiating Cue: You have relieved the OAC on the 07-i 900 watch due to a sudden Shiftly illness. He was performing but unable to complete OST-020, accept ability of the Surveillances. Perform Section 8.2.3, evaluate the ions in the instrument readings, document any unsatisfactory condit ble comments section of Attachment 10.1 and identify any applica Technical Specifications require ments.

Time Critical Task: NO 2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Job Performance Measure Form ES-C-i Appendix C Worksheet Validation Time: 25 minutes NUREG 1021, Revision 9, Supplement I 2011-2 NRC JPM SRDA2

Page 3 of 11 Form ES-C-i Appendix C PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Examiners Cue: Provide OST-020.

Performance Step: I Review procedure OST-020.

t.

Standard: Reviews Precautions and Limitations and remainder of handou Examiners Note:

Comment:

Performance Step: 2 IF MODE 1, 2 OR 3 shiftly checks are required, THEN

)

PERFORM CHANNEL CHECK for the following: (Step 8.2.3.1

1. PZR Level (Channels Ll-459A, 460 and 461) that Standard: Candidate compares the channel readings and determines all channels are within 5% for PZR level.

Examiners Note:

Comment:

NUREG 1021, Revision 9, Supplement 1 2011-2 NRC JPM SROA2

Page 4 of 11 Form ES-C-i Appendix C PERFORMANCE INFORMATION

• Performance Step: 3 IF MODE 1, 2 OR 3 shiftly checks are required, THEN

)

PERFORM CHANNEL CHECK for the following: (Step 8.2.3.2

2. PZR Pressure (Channels P1-455, 456 and 457) that Standard: Candidate compares the channel readings and determines channel P1-455 is outside of the tolerance of 40 psig from the for other 2 channels. ITS Table 3.3.2-1 Items 1 .d and 6.a apply 1 .d to Place the channe l in Mode 3. Condition D applies for Item hours. Condit ion H trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 4 within 18 require d state applies for Item 6.a to Verify the interlock is in the 13 for existing unit condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in Mode 4 within hours.

7 is Examiners Note: ITS Table 3.3.1-1, Items 7.a and 7.b do not apply. Item applicable in Modes I and 2. The unit is in Mode 3.

greater The interlock verification for PZR Pressure being PERM IT 2X2 than 2000 psig is the LO PRESS SI BLOCK status light is extinguished.

Comment:

NUREG 1021, Revision 9, Supplement 1 2011-2 NRC JPM SROA2

Appendix C Page 5 of 1 1 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 4 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.3)

SIG Pressure for S/G A (Channels P1-474, 475 and 476)

S/G Pressure for SIG B (Channels P1-484, 485 and 486)

SIG Pressure for SIG C (Channels P1-494, 495 and 496)

Standard: Candidate compares the channel readings and determines that channel P1-484 is outside of the tolerance of 70 psig from the other 2 channels for SIG B. ITS Table 3.3.2-i Items i .e, I .g and 4.e apply for Mode 3. Condition D applies for Items 1 .e, 1 .g and 4.e to Place the channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 4 within 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br />.

Examiners Note:

ITS Table 3.3.3-1, Item 20 does not apply due to the required channels for steam generator pressure is 2 per SIG. The remaining channels for SIG B are operable and satisfy the specification.

Comment:

2011-2 NRC JPM SRO A2 NUREG 1021, Revision 9, Supplement 1

Page 6 of 11 Form ES-C-i Appendix C PERFORMANCE INFORMATION

• Performance Step: 5 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.4)

SIG Level for S/G A (Channels LI-474, 475 and 476)

SIG Level for SIG B (Channels Ll-484, 485 and 486)

S/G Level for SIG C (Channels LI-494, 495 and 496)

Standard: Candidate compares the channel readings and determines that channel LI-475 is outside of the tolerance of 5% from the other 2 channels for SIG A. ITS Table 3.3.8-1 Item 1 applies for Mode 3.

Condition C applies for Item 1 to Place the channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 4 within 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br />.

Examiners Note:

ITS Table 3.3.1-1 Items 13 and 14 are applicable in Modes I and 2. The unit is in Mode 3.

ITS Table 3.3.3-1 Item 13 for Steam Generator Water Level (Narrow Range) does not apply due to the other 2 remaining S!G level channels are operable. The specification requires 2 per S!G.

Comment:

Performance Step: 6 IF MODE 1,2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.5)

Steam Header Pressure (Channels Pl-464A, 466 and 468)

Standard: Candidate compares the channel readings and determines all of the Steam Header pressure channels are within the tolerance of 70 psig.

Examiners Note:

Comment:

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Page 7 of ii Form ES-C-i Appendix C PERFORMANCE INFORMATION Performance Step: 7 IF MODE 1 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.6)

SIG Steam Flows for S/G A (Channels FI-474 and 475)

SIG Steam Flows for S/G A (Channels FI-484 and 485)

SIG Steam Flows for S/G A (Channels FI-494 and 495)

Standard: Candidate compares the channel readings and determines that all of the steam flow channels are within the specified tolerance.

Examiners Note:

Comment:

• Performance Step: 8 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.7)

Tavg (Channels TI-412D, 422D and 432D)

Standard: Candidate compares the channel readings and determines that channel TI-432D is outside of the tolerance of 4°F from the other channels for Tavg. ITS Table 3.3.2-1 Items 1 .f, 4.d and 6.b apply for Mode 3. Condition D applies for Items 1 .f, 4.d and 6.b to Place the channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 4 within 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br />. Condition H applies for Item 6.b to Verify the interlock is in the required state for existing unit condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in Mode 4 within 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />.

Examiners Note: The interlock verification for Tavg being greater than 543°F is the STEAM DUMP T-AVG CONTROL BLOCKED 2 X 2 status light is extinguished.

Comment:

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Page 8 of 1 1 Form ES-C-i Appendix C PERFORMANCE INFORMATION Performance Step: 9 IF MODE 1, 2CR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.8)

SI Accumulator A Level (LI-920 and 922)

SI Accumulator B Level (LI-924 and 926)

SI Accumulator C Level (LI-928 and 930) of Standard: Candidate compares the channel readings and determines all ls are within the toleran ce of 5%.

the SI Accumulator level channe Examiners Note:

Comment:

Performance Step: 10 IF MODE 1, 2CR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.9)

SI Accumulator A Pressure (P1-921 and 923)

SI Accumulator B Pressure (P1-925 and 927)

SI Accumulator C Pressure (P1-929 and 931) all of Standard: Candidate compares the channel readings and determines ce of the SI Accumulator pressure channels are within the toleran 40 psig.

Examiners Note:

Comment:

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Form ES-C-I Page 9 of 1 1 Appendix C N PERFORMANCE INFORMATIO END OF TASK have been evaluated, Terminating Cue: When the instrument readings c readings and the comments made for any out of spe on requirements have been applicable Technical Specificati s JPM is complete.

identified, the evaluation on thi STOP TIME:

ent 1 NUREG 1021, Revision 9, Supplem 2011-2 NRC JPM SROA2

Page 10 of 11 Form ES-C-i Appendix C VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM SRO A2 Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Date:

Examiners Signature:

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement I

Appendix C Page 1 1 of 1 1 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

INITIATING CUE: You have relieved the OAC on the 07-1900 watch due to a sudden illness. He was performing but unable to complete OST 020, ShiftIy Surveillances. Perform Section 8.2.3, evaluate the acceptability of the instrument readings, document any unsatisfactory conditions in the comments section of Attachment 10.1 and identify any applicable Technical Specifications requirements.

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Section 8.2 Page 8 of 17

!NiI INUI 8.2.2.10 (Continued) 07-19 19-07 t)

c. CALCULATE deviation: LOG (highes minus LOG (lowest) equals:

d. PEER CHECK calculation.

DOCUMENT results ( 1.48). SAT I UNSAT e.

(Circle one required, THEN 8.2.3 IF MODE 1, 2, OR 3 shiftly checks are following:

PERFORM CHANNEL CHECK for the hest and The foll owi ng che ck is to dete rmine the deviation between the hig NOTE: ant ors for the same parameter. The redund lowest channel of redundant indicat is gre ater than d in blocks. If the actual deviation indicators to be compared are groupe of the max imu m allo wed dev iati on as sho wn (deviation of 5% of the full range the it is vem ent, exc ept for SIG Ste am Flo w when <20% rated thermal power),

indicators mo unacceptable. (ESR 97-00601)

1. PZR Level and (ITS SR 3.3.1.1, Table 3.3.1-1 Item 8 3-1 Item 12)

ITS SR 3.3.3.1, Table 3.3.

MAXIMUM CALCULATION INSTRUMENT INSTRUMENT NUMBER RANGE DEVIATION RNP-I/INST-1060 LI-459A 5%

LI-460 0-100%

LI-461 Rev. 41 Page 18 of 54 OST-020

Section 8.2 Page 9 of 17 INIT INIT 8.2.3 (Continued) 07-19 19-07

2. PZR Pressure ating IF Pressurizer Pressure is outside the indic THE N mark N/A.

range due to normal plant conditions, 7.b and (ITS SR 3.3.1.1, Table 3.3.1-1 Item 7.a, 6.a)

ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.d and MAXIMUM CALCULATION NUMBER INSTRUMENT INSTRUMENT RANGE DEVIATION RNP-I/INST-1042 P1-455 1700-2500 psig 40 psig P1-456 P1-457

3. SIG Pressure 1.g and 4.e, (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.e, ITS SR 3.3.3.1, Table 3.3.3-1 Item 20)

MAXIMUM CALCULATION INSTRUMENT INSTRUMENT NUMBER RANGE DEVIATION RNP-IIINST-1 072 P1-474 70 psig P1-475 0-1400 psig P1-476 RNP-I/INST-1072 P1-484 70 psig P1-485 0-1400 psig P1-486 RNP-I/INST-1072 P1-494 0-1400 psig 70 psig P1-495 P1-496 Rev. 41 Page 19 of 54 OST-020

Section 8.2 Page 10 of 17 INIT INIT 8.2.3 (Continued) 07-19 19-07

4. SIG Level (ITS SR 3.3.1.1, Table 3.3.1-1 Item 13 and 14, ITS SR 3.3.3.1, Table 3.3.3-1 Item 13, ITS SR 3.3.8.1, Table 3.3.8-1 Item 1)

MAXIMUM CALCULATION INSTRUMENT INSTRUMENT DEVIATION NUMBER RANGE RNP-I/INST-1070 LI-474 LI-475 0-100% 5%

LI-476 RNP-I/INST-i 070 LI-484 LI-485 0-100% 5%

LI-486 RNP-I/INST-1 070 LI-494 LI-495 0-100% 5%

LI-496

5. Steam Header Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.e)

MAXIMUM CALCULATION INSTRUMENT INSTRUMENT DEVIATION NUMBER RANGE RNP-I/IN ST-i 050 PI-464A P1-466 0-1400 psig 70 psig P1-468 Rev. 41 Page 20 of 54 OST-020

Section 8.2 Page 11 of 17 8.2.3 (Continued)

JNiI INJI 07-19 19-07

6. SIG Steam Flow (ITS SR 3.3.1.1, Table 3.3.1-1 Item 14 and ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.f, 1.g, 4.d and 4.e) (ESR 97-00601)

IF 20% rated thermal power, THEN check the following:

MAXIMUM DEVIATION CALCULATION NSTRUMENT INSTRUMENT RANGE NUMBER 6

0.2x p ph lO RNP-I/INST-1040 FI-474 6 pph 0-4x10 FI-475 0-4x1 06 pph pph 0.2x1 O 6 RNP-l/INST-1 040 Fl-484 F 1-485 6 pph 0-4x10 6 0.2x p ph lO RNP-l/INST-1040 FI-494 FI-495 IF <20% rated thermal power, THEN check the following:

INSTRUMENT_j_INSTRUMENT RANGE MAXIMUM DEVIATION 0-4x1 06 pph pph 0.4x1 O 6

F 1-474 FI-475 between the following combinations:

FI-474 AND FI-475

• FI 474 Fl-477

• FI_475 44j_Fl-476 0-4x1 6

pph 0.4x p

6 ph lO FI-484 FI-485 between the following combinations:

FI-484 AND Fl-485

• Fl 484 AND FI-487

• FI_485_AND_FI-486 0-4x1 06 pph pph 0.4x1 O 6

F 1-494 FI-495 between the following combinations:

Fl-494 AND Fl-495

• FI 494 AND F 1-497

• FI 495 AND FI-496 st the corresponding The Steam Flow Channel is checked again Feed Flow channel for acceptance.

Rev. 41 Page 21 of 54 OST-020

Section 8.2 Page 12 of 17 INIT INIT 8.2.3 (Continued) 07-19 19-07

7. Tavg IF Tavg is outside the indicating range due to normal plant conditions, THEN mark N/A.

6.b)

(ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.f, 4.d and INSTRUMENT TI-4 1 2D INSTRUMENT RANGE I MAXI MUM DEVIATION CALCULATION NUMBER WCAP 11889 540-615°F 4F TI-422D TI-432D

8. SI Accumulator Level (TRMS TR 4.2.1)

MAXIMUM CALCULATION INSTRUMENT INSTRUMENT DEVIATION NUMBER RANGE 0-100% 5% RNP-IIINST-1052 LI-920 LI-922 0-100% 5% RNP-I/INST-1052 LI-924 LI-926 5% RNP-I/INST-1052 LI-928 0-100%

LI-930

9. SI Accumulator Pressure (TRMS TR 4.2.1)

MAXIMUM CALCULATION INSTRUMENT INSTRUMENT DEVIATION NUMBER RANGE 40 psig RNP-I/INST-1036 P1-921 0-800 psg P1-923 40 psig RNP-i/INST-1036 P1-925 0-800 psig P1-927 40 psig RNP-I/INST-1036 P1-929 0-800 psig P1-93 1 Rev. 41 Page 22 of 54 OST-020

-4. N B STEAM GENERATOR LI-484 Fl-486 LI.-485 F-487 LI-486 P1-484 Fl-484 P1-485 FI-485 P1-486

PZR PRESSURES AND LEVELS LI-460 L-461 LI-462 P1-458 LI-459A P1-456 P1-457 P1-444 P1-445 P1-455

Pr4004 PI-464A i-hl66 P1-468 LI-1417A1 P1-4461 P1-4471

c PROTECTION TAVG AND g TI-41 2C TI-41 2A TI422C IT122A 1T1432c IT1432 I I

RPS Inst rurnentati on 3.3.1 Table 33.1-1 (page 2 of 1)

Reactor Protection System Instrumentation APPLICABLE MODES NOMINAL OR OTHER TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE SETPOINT FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (1)

5. Overtemperature AT 1.2 3 E SR 3.3.1.1 Refer to Refer to SR 3.3.1.3 Note 1 Note 1 SR 3.3.1.6 (Page (Page SR 3.3.1.7 3.3-18) 3.3-18)

SR 3.3.1.12 (3)

6. Overpower AT 1.2 3 E SR 3.3.1.1 Refer to Refer to SR 3.3.1.3 Note 2 Note 2 SR 3.3.1.6 (Page (Page SR 3.3.1.7 3.3-19) 3.3-19)

SR 3.3.1.12 (3)

7. Pressurizer Pressure

a. Low i(f) 3 H SR 3.3.1.1 1844 1832.02 SR 3.3.1.7 psig psig SR 3.3J.10

b. High 1.2 3 E SR 3.3.1.1 s 2381.11 2376 SR 3.3.1.7 psig psig

• SR 3.3.1.10

8. Pressurizer Water 3 H SR 3.3.1.1 91.64% 91%

Level High SR 3.3.1.7 SR 3.3.1.10 (continued)

(1) A channel is OPERABLE with an actual Trip Setpoint value found outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is re-adjusted to within the established calibration tolerance band of the Nominal Trip Setpoint.

(3) The Nominal Trip Setpoint is as stated unless reduced as required by LCD 3.2.1 Required Action A.2.3.

(f) Above the P-i (Low Power Reactor Trips Block) interlock.

HBRSEP Unit No. 2 3.3-14 Amendment No. 176

RPS Instrunientati on 3.3.1 Table 3.3.1-1 (page 3 of 7)

Reactor Protection System Instrumentation APPLICABLE MODES NOMINAL OR OTHER TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE SETPOINT FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (1)

9. Reactor Coolant Flow Low 1

( g) 3 per N SR 3.3.1.1 93.47X 94.26

a. Single Loop loop SR 3.3.1.7 SR 3.3.1.10

b. Two Loops 3 per M SR 3.3.1.1 93.47X 94.26 loop SR 3.3.1.7 SR 3.3.1.10

10. Reactor Coolant Pump (RCP) Breaker Position 1

g ) 1 per 0 SR 3.3.1.14 NA NA

a. Single Loop RCP

b. Two Loops 1 per M SR 3.3.1.14 NA NA RCP

11. Undervoltage l) 1 per M SR 3.3.1.9 2959 V 3120 V RCPs bus SR 3.3.1.10

12. Underfrequency 1 per H SR 3.3.1.10 57.84 58.2 Hz RCPs bus SR 3.3.1.14 Hz

13. Steam 1,2 3 per SG E SR 3.3.1.1 15.36t 16t Generator (SG) SR 3.3.1.7 Water Level Low SR 3.3.1.10 Low (continued)

(1) A channel is OPERABLE with an actual Trip Setpoint value found outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is re-adjusted to within the established calibration tolerance band of the Nominal Trip Setpoint.

(f) Above the P-i (Low Power Reactor Trips Block) interlock.

(g) Above the P-B (Power Range Neutron Flux) interlock.

(h) Above the P-i (Low Power Reactor Trips Block) interlock and below the P-8 (Power Range Neutron Flux) interlock.

HBRSEP Unit No. 2 3.3-15 Amendment No. 176

RPS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 of 7)

Reactor Protection System Instrumentation APPLICABLE MODES NOMINAL OR OTHER TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE SETPOINT FUNCTION CONDITIONS CHAIINELS CONDITIONS REQUIREMENTS VALUE (1)

14. SB Water 1,2 2 per SB E SR 3.3.1.1 29.36t 30 Level Low SR 3.3.1.7 SR 3.3.1.10 Coincident with 1,2 2 per SB E SR 3.3.1.1 7.01 E5 6.4 E5 Steam SR 3.3.1.7 ibm/hr ibm/hr Flow/Feedwater Flow SR 3.3.1.10 Mismatch

15. Turbine Trip 3 P SR 3.3.1.10 40.87 45 psig

a. Low Auto Stop SR 3.3.1.15 psig Oil Pressure

b. Turbine Stop 2 P SR 3.3.1.15 NA Valve Closure NA

16. Safety 1.2 2 trains Q SR 3.3.1.14 NA NA Injection (SI) -

Input from Engineered Safety Feature Actuation System (ESFAS)

(continued)

(1) A channel is OPERABLE with an actual Trip Setpoint value found outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is re-adjusted to within the established calibration tolerance band of the Nominal Trip Setpoint.

(f) Above theP-7 (Low Power Reactor Trips Block) interlock.

HBRSEP Unit No. 2 3.3-16 Amendment No. 210

ESFAS INSTRUMENTATION 3.3.2 Table 3.3.2-1 (page 1 of 4)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE NOMINAL MODES OR TRIP OTHER REQUIRED SURVEILLANCE ALLOWABLE SETPOINT SPECIFIED CHANNELS CONDITIONS REQUIREMENTS VALUE (1)

FUNCTION CONDITIONS

1. Safety Injection 2 8 SR 3.3.2.6 NA NA

a. Manual Initiation 1.2,3.4 2 trains C SR 3.3.2.2 NA NA

b. Automatic 1,2,3,4 Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays 3 E SR 3.3.2.1 4.45 psig 4 psig

c. Containment 1.2,3,4 Pressure - High SR 3.3.2.4 SR 3.3.2.7 3 D SR 3.3.2.1 1709.89 1715 psig

d. Pr ssurizer l,2,3 ressure - Low SR 3.3.2.4 psig SR 3.3.2.7 (a) 123 D SR 3.3.2.1 83.76 100 psig

e. Steam Line High 3 per SR 3.3.2.4 psig Differential steam Pressure Between line SR 3.3.2.7 116 24 Steam Header and psig Steam Lines 2 per D SR 3.3.2.1 Cc) (d)

f. High Steam Flow in Two Steam Lines steam SR 3.3.2.4 line SR 3.3.2.7 1 per D SR 3.3.2.1 541.50 543°F Coincident with Tavg - Low loop SR 3.3.2.4 SR 3.3.2.7 2 per D SR 3.3.2.1 Cc) Cd)

g. High Steam Flow in Two Steam Lines steam SR 3.3.2.4 line SR 3.3.2.7 1 per D SR 3.3.2.1 605.05 614 psig Coincident with Steam Line loop SR 3.3.2.4 psig Pressure - Low SR 3.3.2.7 (continued) tolerance band (1) A channel is OPERABLE with an actual Trip Setpoint value found outside its calibration Value and the provided the Trip Setpoint value is conservative with respect to its associated Allowable Trip Setpoint.

channel is re-adjusted to within the established calibration tolerance band of the Nominal (a) Above the Pressurizer Pressure interlock.

(b) Above the Tavg-Low interlock.

flow below 20% load, and Cc) Less than or equal to a function defined as tP corresponding to 41.58% full steam load, and tP increasing linearly from 41.58% full steam flow at 20% load to 110.5% full steam flow at 100%

AP corresponding to 110.5% full steam flow above 100% load.

20% load and then a liP Cd) A function defined asP corresponding to 37.25% full steam flow between 0% and load.

increasing linearly from 37.25% steam flow at 20% load to 109% full steam flow at 100%

HBRSEP Unit No. 2 3.3-25 Anindrnent No. 196

ESFAS Instrumentat 3..2 Table 3.3.2-1 (page 3 of 4)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE NODES OR NOMINAL OTHER TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE SETPOINT FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (1)

4. Steam Line Isolation

a. Manual Initiation 12

(

3 (e) e) 1 per F SR 3.3.2.6 NA NA steam line

b. Automatic Actuation 12

(

3 (e) e) 2 trains G SR 3.3.2.2 NA NA Logic and Actuation SR 3.3.2.3 Relays SR 3.3.2.5

c. Containment 3

(

2 1

( e) e), 6 D SR 3.3.2.1 10.45 10 psig PressureHigh High (2 sets SR 3.3.2.4 psig of 3) SR 3.3.2.7

d. High Steam Flow in 3 2

1

( e),

e> 2 per D SR 3.3.2.1 Cc) (d)

Two Steam Lines steam SR 3.3.2.4 line SR 3.3.2.7 Coincident with 1

(

2

, e) 1 per D SR 3.3.2.1 541.50 S43F Tavg- LOW loop SR 3.3.2.4

- 3

( e SR 3.3.2.7

e. High Steam Flow in 3

(

2 1

( e) e), 2 per D SR 3.3.2.1 Cc) Cd)

Two Steam Lines steam SR 3.3.2.4 line SR 3.3.2.7 Coincident with 12

(

3 (e) e) 1 per D SR 3.3.2.1 605.05 614 psig Steam Line steam SR 3.3.2.4 psig PressureLow line SR 3.3.2.7 (continued)

(1) A channel is OPERABLE with an actual Trip Setpoint value found outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is re-adjusted to within the established calibration tolerance band of the Nominal Trip Setpoint.

(b) Above the T Low interlock.

(C) Less than or equal to a function defined as P corresponding to 41.58% full steam flow below 20% load, and AP increasing linearly from 41.58% full steam flow at 20% load to 110.5% full steam flow at 100% load, and 1P corresponding to 110.5% full steam flow above 100% load.

(d) Less than or equal to a function defined as AP corresponding to 37.25% full steam flow between 0% and 20%

load and then a liP increasing linearly from 37.25% steam flow at 20% load to 109% full steam flow at 100%

load.

(e) Except when all MSIVs are closed.

HBRSEP Unit No. 2 3.3-27 Arnendrnnt No. 176 187

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 4)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR NOMINAL OTHER TRIP SPECIFIED REQuiRED SURVEILLANCE ALLOWABLE SETPOINT FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE (1)

5. Feedwater Isolation

a. Automatic 2 trains G SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.32.5 Relays

b. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

6. ESFAS Interlocks

a. Pressurizer 1,2.3 3 H SR 3.3.2.1 2005.11 2000 Pressure Low SR 3.3.2.4 psig psig SR 3.3.2.7

b. TaVgLOW 1,2.3 1 per H SR 3.3.2.1 544.50 543°F loop SR 3.3.2.4 °F SR 3.3.2.7 (1) A channel is OPERABLE with an actual Trip Setpoint value found outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is re-adjusted to within the established calibration tolerance band of the Nominal Trip Setpoint.

(f) Except when all MFIVs, MFRVs. and bypass valves are closed or isolated by a closed manual valve.

HBRSEP Unit No. 2 3.3-28 Amendment No. 176

PAM Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation

[CO 3.3.3 The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS NOTE Separate Condit ion entry is allowe d for each Function.

REQUIRED ACTION COMPLETION TIME CONDITION A. NOTE A.1 Restore required 30 days Not applicable to channel to OPERABLE Functions 3, 4, 19, status.

22, 23, and 24.

One or more Functions with one required channel inoperable.

B. Required Action and 8.1 Initiate action in Immediately associated Completion accordance with Time of Condition A Specification 5.6.6 not met.

(continued)

[IBRSEP Unit No. 2 3.3-29 Amendment No. 203

PAM Instrumentation 3.3.3 ACTIONS (continued)

REQUIRED ACTION COMPLETION TIME D CONDITION One or more Functions C.1 Restore one channel 7 days C.

with two required to OPERABLE status.

channels inoperable.

D. NOTE D.1 Restore required 7 days Only applicable to channel to OPERABLE Functions 3, 4, 19, status.

22, 23, and 24.

One or more Functions with one required channel inoperable.

E. Required Action and El. Enter the Condition Immediately associated Completion referenced in Time of Condition C or Table 3.3.3-1 for the D not met. channel.

F. As required by F.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Required Action E.1 and referenced in AND Table 3.3.3-1.

F.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued)

HBRSEP Unit No. 2 3.3-30 Amendment No. 216

PAM Instrumentation 3.3-3 Table 33.3-1 (page 1 of 1)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROII FUNCTION REQUIRED CHANNELS REQUIRED ACTION E.1

1. Power Range Neutron Flux 2 F

2. Source Range Neutron Flux 2 F

3. Reactor Coolant System (RCS) Hot Leg 1 per loop F Temperature

4. RCS Cold Leg Temperature 1 per loop F

5. RCS Pressure (Wide Range) 2 F

6. Refueling Water Storage Tank Level 2 F

7. Containment Sump Water Level (Wide Range) 2 G

8. Containment Pressure (Wide Range) 2 G

9. Containment Isolation Valve Position 2 per penetration flow F (a)(b) path

10. Containment Area Radiation (High Range) 2 6

11. Not used

12. Pressurizer Level 2 F

13. Steam Generator Water Level (Narrow Range) 2 per SG F

14. Condensate Storage Tank level 2 F

15. Core Exit TemperatureQuadrant 1 F

16. Core Exit TemperatureQuadrant 2 2 F (c) 2 F

17. Core Exit TemperatureQuadrant 3 2

( c) F

18. Core Exit TemperatureQuadrant 4

19. Auxiliary Feedwater Flow SD AFW Pump 1 per SG G MD AFW Pump 1 per SG G

20. Steam Generator Pressure 2 per SG F

21. Containment Spray Additive Tank Level 2 F

22. PORV Position (Primary) 1 G

23. PORV Block Valve Position (Primary) 1 6

24. Safety Valve Position (Primary) 1 G one closed and (a) Not required for isolation valves whose associated penetration is isolated by at least blind flange, or check valve with flow through the valve deactivated automatic valve, closed manual valve, secured.

one installed (b) Only one position indication channel is required for penetration flow paths with only automatic containment isolation valve.

(c) A channel consists of one core exit thermocouple (CET).

HBRSEP Unit No. 2 3.3-32 Amendment No. 216

Auxiliary Feedwater (AFW) System Instrumentation 3.3.8 Table 3.3.8-1 (page 1 of 1)

Auxiliary Feedwater System Instrumentation APPLICABLE NOMINAL MODES OR TRIP OTHER SETPOINT SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE CHANNELS CONDITIONS REQUIREMENTS VALUE (1)

FUNCTION CONDITIONS 3 per SG C SR 3.3.8.1 1S.36X 16

1. SG Water LevelLow Low 1.2,3 SR 3.3.8.2 SR 3.3.8.4 all

2. Safety Injection Refer to LCO 3.3.2. ESFAS Instrumentation. Function 1. for initiation functions and requirements.

2 per D SR 3.3.8.3 NA 328 V +/-

3. Loss of Offsite Power 1,2,3 lOX bus SR 3.3.8.4 with 1 sec time delay B SR 3.3.8.3 2959 V 3120 V

4. Undervoltage Reactor 1.2.3 2 per Coolant Pump bus SR 3.3.8.4 1 per E SR 3.3.8.3 NA NA

5. Trip of all Main 1,2 Feedwater Pumps pump tion tolerance band (1) A channel is OPERABLE with an actualTrip Setpoirit value found outside its calibra ted Allowable Value and the provid ed the Trip Setpoi nt value is conser vative with respec t to its associa the Nominal Trip channel is re-adjusted to within the established calibration tolerance band of Setpoi nt.

HBRSEP Unit No. 2 3.3-47 Amendment No. 176

Miscellaneous Test Requiremen ts 4.0 4.0 MISCELLANEOUS TEST_REQUIREMENTS FREQUENCY TEST ment and Continuously TR 4.1.1 Radiation levels in the contain be (CTS 3.8.1.c) spent fuel storage areas shall rations.

monitored during refueling ope ulator Level 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> TR 4.2.1 Perform CHANNEL CHECK of Accum (CTS Table and Pressure.

4.1-1 item 23)

Acid Tank 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> TR 4.2.2 Perform CHANNEL CHECK of Boric (CTS Table Level.

4.1-1 item 14) s Tubes. 7 days TR 4.2.3 Rod Boric Acid Tank Level Bubbler (CTS Table 4.1-1 item 14)

Charging 18 months TR 4.2.4 Perform CHANNEL CALIBRATION of (CTS Table Flow.

4.1-1 item 12) idual 18 months TR 4.2.5 Perform CHANNEL CALIBRATION of Res (CTS Table Heat Removal Pump Flow.

4.1-1 item 13) ic Acid 18 months TR 4.2.6 Perform CHANNEL CALIBRATION of Bor (CTS Table Tank Level.

4.1-1 item 14)

(continued) 4.0-1 PLP-100 Rev. 0 HBRSEP Unit No. 2

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

REQUIRED ACTION COMPLETION TIME CONDITION H.1 Verify interlock is 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> H. One channel inoperable, in required state for existing unit condition.

OR H.2.1 Be in MODE 3. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> AND H.2.2 Be in MODE 4. 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br /> 1.1 Restore train to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> I. One train inoperable OPERABLE status.

OR 1.2.1 Be in MODE 3 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> AND 1.2.2 Be in MODE 4 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br /> AND 1.2.3 Be in MODE 5 37 hours4.282407e-4 days <br />0.0103 hours <br />6.117725e-5 weeks <br />1.40785e-5 months <br /> 3.3-23 Amendment No. 176 HBRSEP Unit No. 2

irislrumeriLatlOn 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One train inoperable. C.1 Restore train to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OPERABLE status.

OR C.2.1 Be in MODE 3. 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> AND C.2.2 Be in MODE 5. 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />

0. One channel 0.1 Place channel in inoperable. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> trip.

OR 0.2.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND D.2.2 Be in MODE 4. 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> E. One Containment E.1 Place channel in Pressure channel 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> trip.

inoperable.

OR E.2..1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND E.2.2 Be in MODE 4. 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> AND E.2.3 Be in MODE 5. 42 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br /> (continued)

HBRSEP Unit No. 2 3.3-21 Amendment No. 176

.-c;) A Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 02344100403 Task

Title:

Calculate Emergency Dose JPM No.: 2011-2 NRC Admin JPM Exposure Time Limits SRO A3 K/A

Reference:

G2.3.4 3.2/3.7 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator 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:

• An Emergency Event has been declared.

• Re-entry individual has received 1240 mR TEDE dose this year at RNP.

• There are 2 jobs that must be performed to stabilize the plant and protect the equipment:

o Valve LCV-1 1 5B, RWST to Charging Pump Suction, air line needs to be re-attached to the valve operator.

o Seal Injection Filter B must be placed in service due to Filter A clogged.

• All valves are located in a 48 R/hr field.

Task Standard: Determines Stay Time Required Materials: Calculator EPOSC-04, EMERGENCY WORK CONTROL General

References:

EPOSC-04, EMERGENCY WORK CONTROL Handouts: EPOSC-04, EMERGENCY WORK CONTROL 2011-2 NRC Admin JPM SRO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-I Worksheet Initiating Cue: Calculate how long the individual can remain in the radiation area without exceeding the applicable emergency exposure limits.

Time Critical Task: NO Validation Time: 8 minutes 2011-2 NRC Admin JPM SRO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 6 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk )

Start Time:

EPOSC-04, EMERGENCY WORK CONTROL

• Performance Step: i The table shown below identifies the emergency worker dose limits. In addition to the categories listed in the table, doses should be limited as follows:

1. The lens of the eye should be limited to three (3) times the stated TEDE value.

2. Any other organ (including skin and body extremities) should be limited to ten (10) times the stated TEDE value.

(Step 8.7.2)

Dose Limit Activity Condition 5 REM All 10 REM Repair and reentry Lower dose not practical efforts 25 REM Lifesaving or Lower dose not practical protection of large populations

>25 REM Lifesaving or Only on a voluntary basis protection of large to persons fully aware of populations the risks involved Standard: Candidate selects 10 REM Dose Limit for Repair efforts Examiners Cue:

Examiners Note:

Comment:

2011-2 NRC Admin JPM SROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 6 Form ES-C-i PERFORMANCE INFORMATION

• Performance Step: 2 10R HR 60 Mm 48R HR = 12.5 Minutes Dose Dose Conversion Time Limit Limit Rate Standard: Candidate calculates 12.5 minutes total stay time.

Examiners Cue:

Comment:

END OF TASK Terminating Cue: Candidate calculates Stay Time STOP TIME:

2011-2 NRC Admin JPM SRO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 6 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC Admin JPM SRO A3 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 Admin JPM SROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 6 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

• An Emergency Event has been declare d.

• Re-entry individual has received 1240 mR TEDE dose this year at RNP.

• There are 2 jobs that must be perform ed to stabilize the plant and protect the equipment:

o Valve LCV-1 1 5B, RWST to Cha rging Pump Suction, air line needs to be re-attached to the valve operator.

o Seal Injection Filter B must be placed in service due to Filter A clogged.

• All valves are located in a 48 R/hr field.

Initiating Cue: Calculate how long the individual can remain in the radiation area without exceeding the applicable eme rgency exposure limits.

2011-2 NRC Admin JPM SROA3 NUREG 1021, Revision 9, Supplement I

9 ,

q 4 9 ATTACHMENT 10.5 Page 1 of 11 NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM a I .3RILL

2. INITIAL MACTUAL EVENT 9L)..OW-UP NOTIFICATION: TIME______ DATE I I MESSAGE#

AUTHEN11CATION#______

/

3. SITE: Confirmation Phone #

3),3 _3 .

4. EMERGENCY UNUSUAL EVENT [J ALERT ITE AREA EMERGENCY GENERAL 4%,fi,iL_a

5. PROTECTIVE ACTION RECOMMENDATIONS: NONE 1

EVACUATE I SHELTER CONSIDER THE USE OF KI (POTASSIUM IODIDE) IN ACCORDANCE wrni STATE PI.ANS AND POUCY.

fOTHER

6. EMERGENCY RELEASE: None Is Occuning Has Occurred

7. RELEASE SIGNIFICANCE: Not Within normal Above normal operating Under p licable operating limits lirits evaluation

8. EVENT PROGNOSIS: Improving Stable Degrading ,/

9. METEOROLOGICAL DATA:

(May not be available for Initial Wind Direction from Precipitation C>

/ /degrees rId Speed Stability Class Lf. mph Notifl;ations)

10. DECLARATION (j TERMINATION Time /iJ7 t) Date_____________

11. AFFECTED UNIT(S):

12.UNITSTATUS: UI Power Shutdown at lime___________ Date _1 l_

(Unafcted Unit(s) Status Not Required for Initial Notifications) U2 (9  % Power Shutdown at Time fC (-

Date U3 Power Shutdown at Time Date I I

13. REMARKS:

FOLLOW-UP INFORMATION (LInes 14 through 16 Not Reauired for Initial Notifications)

EMERGENCY RELEASE DATA. NOT REQUIRED IF LINE 6 A IS SELECTED.

14. RELEASE CHARACTERIZATION: TYPE: Elevated Mixed Ground UNITS: Ci Cl/sec Ci/sec MAGNITUDE: Noble Gases:__________ lodines:___________ Particulates:__________ Other FORM: Airborne Start Time Date _I I_Stop Time Date _/ I_

Start Time J Liquid Date _I I_Stop Time Date _/ I_

15. PROJECTION PARAMETERS: Projection period: Estimated Release Duration Projection performed: Time Date _I I_

16. PROJECTED DOSE: DISTANCE TEDE (mRem Adult Thyroid CDE (mRem)

Site boundary 2 Miles 5 Miles 0 iles A

17. APPROVED B Title E. Time ,&tj)

NOTIFIED BY:______________ RECEIVED BY: Time Date I____

J EPNOT-01 I Rev. 37 Page 37 of 68

Cd 0 0 Appendix C Page 3 of 14 Form ES-C-I PERFORMANCE INFORMATION (Th (Denote Critical Steps with an asterisk

)

Start Time: Time Critical Start Time:________

Performance Step: I Obtain the EAL ALL Conditions and COLD Conditions Matrix Standard: Candidate states where to obtain the EALs.

Examiners NOTE: Provide copies of the EAL Matrix to the candidate.

Comment:

Performance Step: 2 EVALUATE ALL Conditions EAL Matrix under all conditions.

(Step 8.3.1)

Standard: Candidate reviews EAL ALL Conditions Matrix and does not identify any classification.

Examiners NOTE:

Comment:

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 4 of 14 Form ES-C-i PERFORMANCE I NFORMATION 0

• Performance Step: 3 IF Reactor Coolant temperature is > 200°F, THEN EVALUATE HOT Conditions EAL Matrix (Step 8.3.2)

Standard: Candidate reviews EAL HOT Conditions Matrix and identifies the following classification: Site Area Emergency FSI.1 Loss or potential loss of any two barriers (Table F-I)

Reactor Coolant System Barrier

• Loss I Containment High Range Monitor R-32A or R-32B> 5 Remlhr.

OR

• Loss 2- RCS leak rate> available makeup capacity as indicated by a loss of RCS subcoollng less than 35°F

[55°9 OR

• Potential Loss 2 Unisolable RCS leak exceeding the capacity of one charging pump (77 gpm)

Containment Barrier

• Potential Loss 7 Containment pressure> 10 psig with <one full train of depressurization equipment operating. (Note: One Containment Spray System train and one Containment Cooling System train comprise one full train of depressurization equipment.)

Examiners NOTE: Candidate will declare a Site Area Emergency and present his classification to you. This will stop the 15 minute clock for the declaration portion of the JPM.

Comment:

Time Critical Stop Time for EAL Classification: (15 Minutes) 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 5 of 14 Form ES-C-I PERFORMANCE INFORMATION Examiners CUE: Present the candidate with the second cue sheet for the JPM task of completing the Emergency Notification Form and a copy of procedure EPNOT-O1.

Time Critical Start Time for EAL Notification:

Performance Step: 4 Candidate will proceed to Attachment 10.7 for a Site Area Emergency and direct the Emergency Communicator to report to the Control Room to assume the duties of the Emergency Communicator.

Standard: Candidate informs the Emergency Communicator to prepare for communication activities.

Examiners NOTE:

Examiners CUE: When the candidate has completed the EAL classification, CUE the candidate that he will manually complete an Emergency Notification Form and submit it to the SEC.

Comment 201 1-2 NRC JPMAdmin SROA4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 6 of 14 Form ES-C-I PERFORMANCE INFORMATION 0

Performance Step: 5 Obtain EPNOT-01, Attachment 10.5, Nuclear Power Plant Emergency Notification Form.

Standard: Copies Attachment from procedure or pulls it from a file.

Examiners NOTE:

Examiners CUE: The Examiner will provide a copy of EPNOT-O1 to the candidate.

Comment:

• Performance Step: 6 Enter Line I information.

Standard: Marks DRILL and Message #1.

Examiners NOTE: Ensure that DRILL is marked. ACTUAL EVENT is only used during a real emergency.

Comment:

• Performance Step: 7 Enter Line 2 information.

Standard: Marks INITIAL.

Examiners NOTE:

Comment:

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 7 of 14 Form ES-C-I PERFORMANCE INFORMATION

• Performance Step: 8 Enter Line 3 information.

Standard: Enters H.B. Robinson as the Site and enters CONFIRMATION PHONE NUMBER.

Examiners NOTE: Identifying the site as H.B. Robinson is critical. Listing the proper confirmation telephone number is NOT critical.

Examiners CUE: When candidate requests the ERO phone list, tell him the Confirmation Phone Number is 843-383-3685.

Comment:

• Performance Step: 9 Enter Line 4 information.

Standard: Marks SITE AREA EMERGENCY as the Emergency Classification.

Based on EAL # FSI.1 EAL Description Loss or potential loss of any two barriers (Table F-I)

Examiners NOTE:

Comment

• Performance Step: 10 Enter Line 5, Protective Action Recommendation information.

Standard: Marks NONE.

Examiners NOTE:

Comment:

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 8 of 14 Form ES-C-I PERFORMANCE iNFORMATION ED

• Performance Step: 11 Enter Line 6, EMERGENCY RELEASE, information.

Standard: Marks NONE.

Examiners NOTE:

Comment:

Performance Step: 12 Enter Line 7, RELEASE SIGNIFICANCE, information.

Standard: Marks NOT APPLICABLE.

Examiners NOTE:

Examiners CUE:

Comment:

Performance Step: 13 Enter Line 8, EVENT PROGNOSIS, information.

Standard: Marks Degrading.

Examiners NOTE:

Comment:

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 9 of 14 Form ES-C-I PERFORMANCE INFORMATION

• Performance Step: 14 Enter Line 9, METEROLOGICAL DATA, information.

Standard: Enters data that was given in the initial conditions:

Wind Direction 145 degrees, Wind Speed()nph, Precipitation 0, Stability Class D.

ExamIners NOTE:

Comment

• Performance Step: 15 Enter Line 10 INFORMATION.

Standard: Marks Block A, DECLARATION: Enters applicable Date and Time.

Examiners NOTE:

Examiners CUE: Date and time should reflect present date and time.

Comment:

Performance Step: 16 Enter Line 11 information, AFFECTED UNITS.

Standard: Marks Unit 2.

Examiners NOTE:

Comment:

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 10 of 14 Form ES-C-I PERFORMANCE INFORMATION 0

Performance Step: 17 Enter Line 12 information UNIT STATUS.

Standard: Enters Shutdown Time: 1021 hours0.0118 days <br />0.284 hours <br />0.00169 weeks <br />3.884905e-4 months <br /> on 1112812011 Examiners NOTE: Reactor shutdown DATE and TIME was given in the initial conditions on the cue sheet.

Examiners CUE:

Comment:

Performance Step: 18 Enter Line 13 Remarks information.

Standard: Enters information describing accident from EAL matrix.

Examiners NOTE: May leave LINE 13, Remarks blank or enter EAL information.

Comment:

• Performance Step: 19 Line 17 APPROVAL by SEC.

Standard: Completes Line 17 with Signature, Title, Time, and Date.

Examiners NOTE:

Comment:

Time Critical Stop Time for EAL Notification: (15 Minutes) 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 11 of 14 Form ES-C-i PERFORMANCE INFORMATION 0

END OF TASK Termination Cue: EAL classification has been determined and notification has been made.

STOP TIME:

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 12 of 14 Form ES-C-I VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM Admin SRO A4 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 JPMAdmin SROA4 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 02344101203 Task

Title:

Classify an Emergency Event JPM No.: 2011-2 NRC JPM Admin SROA4 K!A

Reference:

G2.4.41 (2.914.6)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINE!

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:

• This is a DRILL.

• Unit at 30% RTP with a shutdown in progress lAW GP-006.

• CV Purge is in progress to support upcoming maintenance activities inside the CV.

• CV Spray Pump A is inoperable due to a grounded motor.

• Subsequently, a LOCA and loss of offsite power occurred at 1021 hours0.0118 days <br />0.284 hours <br />0.00169 weeks <br />3.884905e-4 months <br /> on 11/28/2011.

• Emergency Diesel Generator B trips while starting.

• CV pressure peaked at 37 psig.

• Core exit thermocouples are currently reading 304°F.

• R-32A is reading 8 Rem/hr.

• RVLIS indication reads 45%.

• SIG NR levels are currently at A-12%, B-15%, C-32%.

• Weather conditions: Wind direction is from 145 degrees, Wind speed is 4 mph, Stability Class is D, Precipitation is Zero.

• You are the Shift Manager.

Task Standard: Identifies event as an SITE AREA EMERGENCY per FSI.1 Required Materials: EPCLA-01, EPCLA-04, EAL Matrixes, EPNOT-01.

General

References:

EPCLA-01, EPCLA-04, EAL Matrixes, EPNOT-01.

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Job Performance Measure Form ES-C-I Worksheet Handouts: EPCLA-O1, EPCLA-04, EAL Matrixes, EPNOT-OI.

Initiating Cue: Classify the event lAW the EAL matrixes. Upon completion of the event classification, inform the examiner.

This Task is TIME CRITICAL Time Criticai Task: YES (15 minutes for classification AND 15 minutes for notification)

Validation Time: 24 minutes 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 13 of 14 Form ES-C-I JPM CUE SHEET INITIAL CONDITIONS:

• This is a DRILL.

• Unit at 30% RTP with a shutdown in progre ss lAW GP-006.

• CV Purge is in progress to support upcoming inside the CV. maintenance activities

• CV Spray Pump A is inoperable due to a gro unded motor.

• Subsequently, a LOCA and loss of offsite power occurred at 1021 hours0.0118 days <br />0.284 hours <br />0.00169 weeks <br />3.884905e-4 months <br /> on 11/28/2011.

• Emergency Diesel Generator B trips whil e starting.

• CV pressure peaked at 37 psig.

• Core exit thermocouples are currently read ing 304°F.

• R-32A is reading 8 Rem/hr.

• RVLIS indication reads 45%.

• SIG NR levels are currently at A-12%, B-15

%, C-32%.

• Weather conditions: Wind direction is from 145 degrees, Wind speed is 4 mph, Stability Class is 0, Precipitation is Zero.

• You are the Shift Manager.

INITIATING CUE: Classify the event lAW the EAL matrixes.

Upon completion of the event classification, inform the examiner.

This Task is TIME CRITICAL 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 14 of 14 Form ES-C-I JPM CUE SHEET INITIAL CONDITIONS: Emergency event has just bee n

Emergency Coordinator (SEC). declared by the Control Room Site INITIATING CUE: The Emergency Communicator is NOT available. You, as the Control Room Site Emergenc y Coordinator (SEC), must manuall complete the Emergency Notific y ation Form (ENF) from procedure EPNOT-01, CRIEOF Emergenc y Communicator.

This task is TIME CRITICAL.

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Suppl ement I