Text

2005-DRAFT-Operating Exam
	ML052710214
Person / Time
Site:	Arkansas Nuclear
Issue date:	09/15/2005
From:	; NRC Region 4
To:	;
References
	ES-301-1
	Download: ML052710214 (300)
	v • d • e

ES-301 Administrative Topics Outline Form ES-301-1 Facility: ANO-1 Date of Examination: 9-12-05 Examination Level (circle one): RO / SRO Operating Test Number: 1 Type Administrative Topic Describe activity to be performed Code*

(see note)

Conduct of Operations Ability to use plant computer to obtain and evaluate M/S parametric information on system or component status.

A1JPM-RO-PMS1 Rev. 2 2.1.19 (Imp 3.0)

Ability to perform specific and integrated plant Conduct of Operations D/S procedures during all modes of operation.

A1JPM-RO-RBAL3 Rev. 1 2.1.23 (Imp 3.9)

Equipment Control Knowledge of refueling administration requirements.

N/S 2.2.26 A1JPM-RO-REFUL1 Rev. 0 (Imp 2.5)

Radiation Control Ability to control radiation releases.

D/P/S A1JPM-RO-RAD1 Rev. 2 2.3.11 (Imp 2.7)

Emergency Plan NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when all 5 are required.

Type Codes & Criteria: (C)ontrol room (D)irect from bank ( 3 for ROs; 4 for SROs)

(N)ew or (M)odified from bank ( 1 (P)revious ( 1; randomly selected)

(S)imulator ES-301, Page 22 of 27

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-PMS1 Page 1 of 4 UNIT: 1 REV # 2 DATE: ______________________________

TUOI NUMBER: A1JPM-RO-PMS1 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - CONDUCT OF OPERATIONS TASK: OPERATE THE PLANT COMPUTER JTA#: ANO1-RO-PMS-NORM-4 KA VALUE RO: 3.0 SRO: 3.0 KA

REFERENCE:

2.1.19 APPROVED FOR ADMINISTRATION TO: RO: X SRO:

TASK LOCATION: INSIDE CR: X OUTSIDE CR:_________ BOTH:________

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE:_______________ SIMULATOR: PERFORM LAB:_____ _____

POSITION EVALUATED: RO:____ ___ SRO:___________

ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE:__________ LAB:________

TESTING METHOD: SIMULATE:_________ PERFORM:____X_______

APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES REFERENCE(S): 1105.010, Chg. 011-00-0 EXAMINEE'S NAME:________________________________ SSN ______-_____-____________

EVALUATOR'S NAME:__________________________________________________________________

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY:________________ UNSATISFACTORY:_________________

PERFORMANCE CHECKLIST COMMENTS:

____________ Start Time ____________ Stop Time ____________ Total Time SIGNED ________________________________ DATE: _______________________

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-PMS1 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: The plant is at 100% power operations. The Makeup Tank level is at 60 inches. RCS boron concentration is 1000 ppm. BAAT boron concentration is 12,000 ppm.

TASK STANDARD: The examinee uses the plant computer BORON program to calculate a total addition to the Makeup Tank of approximately 600 to 630 gallons consisting of 50 to 52.5 gallons boric acid and 550 to 577.5 gallons of DI water._______

TASK PERFORMANCE AIDS: 1105.010, Plant Monitoring System NOTE: 1105.010 provides instructions for the Plant Monitoring System but the exact manipulations of this task are within the skill of the craft. Therefore, procedure in hand is not required.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-PMS1 Page 3 of 4 INITIATING CUE:

The CRS directs you to use the plant computer to calculate a No Concentration Change to raise the Makeup Tank level to ~80 inches.

CRITICAL ELEMENTS (C) 2, 3, 4, 5 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSA T

1. Select NASP on PMS screen or Selected NASP on PMS.

keyboard. _____ _____ _____

(C) 2. Select BORON program. Selected BORON program on PMS.

(C) 3. Select option No. 5, No Typed 5 and pressed ENTER key Concentration Change. on PMS keyboard. _____ _____ _____

(C) 4. Select option 0, boric acid and DI Typed 0 and pressed ENTER key water addition. on PMS keyboard. _____ _____ _____

(C) 5. Enter values requested by BORON Examinee entered the following program. values:

Makeup volume required (gallons) = 600 to 630 (trainee should calculate the value needed using 20 inches x 30.86 gallons/in.)

Makeup boron concentration required (ppm) = 1000

Available feed solution Boron concentration (ppm) = 12,000 The PMS displayed the following _____ _____ _____

values after entry of final value:

Feed volume DI H2O - 550 to 577.5 gallons

Feed volume boric acid - 50 to 52.5 gallons END

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-PMS1 Page 4 of 4 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:

The plant is at 100% power operations.

The Makeup Tank level is at 60 inches.

RCS boron concentration = 1000 ppm

BAAT boron concentration = 12,000 ppm INITIATING CUE:

The CRS directs you to use the plant computer to calculate a No Concentration Change to raise the Makeup Tank level to ~80 inches.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RBAL3 Page 1 of 5 UNIT: 1 REV # 1 DATE: ______________________________

TUOI NUMBER: A1JPM-RO-RBAL3 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - CONDUCT OF OPERATIONS TASK: ESTIMATE BORON CONCENTRATION REQUIRED TO MAINTAIN SHUTDOWN MARGIN DURING HEATUP USING RHOBAL PROGRAM JTA#: ANO1-RO-OPROC-NORM-70 KA VALUE RO: 3.9 SRO: 4.0 KA

REFERENCE:

2.1.23 APPROVED FOR ADMINISTRATION TO: RO: x SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR:_________ BOTH:____ ____

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE:_______________ SIMULATOR: PERFORM LAB:__________________

POSITION EVALUATED: RO:____ __ SRO:___________

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:__________ LAB:________

TESTING METHOD: SIMULATE:_________ PERFORM:___________

APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): N/A EXAMINEE'S NAME:________________________________ SSN ______-_____-____________

EVALUATOR'S NAME:__________________________________________________________________

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY:________________ UNSATISFACTORY:_________________

PERFORMANCE CHECKLIST COMMENTS:

____________ Start Time ____________ Stop Time ____________ Total Time SIGNED ________________________________ DATE: _______________________

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RBAL3 Page 2 of 5 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: The plant is preparing for startup after a reactor trip. The plant had operated continuously at 100% power since the refueling outage EFPD = 0. RCS Tave = 185°F. Desired final RCS Tave = 532° Heatup is scheduled to commence later today.

TASK STANDARD: The examinee has calculated the required Boron concentration to maintain shutdown margin during heatup using RHOBAL and determined the value to be 1574 to 1600 ppm.

TASK PERFORMANCE AIDS: Personal computer with RHOBAL program available.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RBAL3 Page 3 of 5 INITIATING CUE:

The Control Room Supervisor directs you to calculate Boron concentration required to maintain shutdown margin during heatup using the RHOBAL program.

CRITICAL ELEMENTS (C) 1, 2, 5 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT NOTE: Examinee may start in the Poison menu or in the Shutdown Margin menu.

Either way, the examinee must establish a power history.

(C) 1. Activate Shutdown Margin on pull Clicked (or Alt S via keyboard) on down menu. Shutdown Margin in menu bar.

(C) 2. Run program to determine Boron Performed the following actions:

concentration required to maintain

Clicked on Worksheet 5, "Boron shutdown margin. Concentration Required to Maintain SDM during Cooldown or Heatup.

Entered 0 for Cycle Burnup in EFPD.

Entered 0 for all CRA positions, except 30.4 for APSRs.

Entered 185 for RCS Average Temperature in degrees F.

Entered 532 for Final Desired RCS Average Temperature in degrees F.

NOTE: Step 3 may be performed prior to step 1 via the Poison menu.

3. Activate Xenon and Samarium Clicked (or Alt P via keyboard) on menu. Xenon and Samarium in menu bar.

4. Enter power history. Performed the following actions:

Entered 0% Power Level

Entered todays date.

Entered 0 for Burnup

Clicked on Beginning of cycle concentrations.

Clicked on INITIALIZE POISONS button.

Close "Xenon and Samarium" menu.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RBAL3 Page 4 of 5 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT (C) 5. Determine required Boron Noted the required Boron conc from concentration. Table or Figure B6 to be 1574.

Candidate may discuss different boron concentration requirements for the various temperature ranges during heatup.

Accept 1574 to 1600 for final minimum boron concentration at 532°F.

END

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RBAL3 Page 5 of 5 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:

The plant is preparing for startup after a refueling outage.

The plant had operated continuously at 100% power prior to the refueling outage.

EFPD = 0

RCS Tave = 185°F

Final RCS Tave = 532°F

Heatup is scheduled to commence later today.

INITIATING CUE:

The SM/CRS directs you to calculate Boron concentration required to maintain shutdown margin during heatup to 532°F using the RHOBAL program.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-REFUL1 Page 1 of 4 UNIT: 1 REV # 0 DATE: ______________________________

TUOI NUMBER: A1JPM-RO-REFUL1 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - EQUIPMENT CONTROL TASK: Perform Attachment B of 1502.004, Refueling Boron, Temperature, Tritium, and Level Check JTA#: ANO1-RO-FUELH-NORM-25 KA VALUE RO: 2.5 SRO: 3.7 KA

REFERENCE:

2.2.26 APPROVED FOR ADMINISTRATION TO: RO: X ____ SRO: ___

TASK LOCATION: INSIDE CR: OUTSIDE CR:_________ BOTH:____X___

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE:_______________ SIMULATOR: PERFORM LAB:__________________

POSITION EVALUATED: RO:___ __ SRO:___________

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:__________ LAB:________

TESTING METHOD: SIMULATE:_________ PERFORM:___________

APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1502.004, Chg. 034-02-0 EXAMINEE'S NAME:________________________________ SSN ______-_____-____________

EVALUATOR'S NAME:__________________________________________________________________

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY:________________ UNSATISFACTORY:_________________

PERFORMANCE CHECKLIST COMMENTS:

____________ Start Time ____________ Stop Time ____________ Total Time SIGNED ________________________________ DATE: _______________________

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-REFUL1 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: A refueling outage is in progress. Fuel handling is in progress.

TASK STANDARD: The examinee has correctly identified that VEF-15 should be running and stated the requirements of note 3 of Att. B.

TASK PERFORMANCE AIDS: 1502.004 Att. B

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-REFUL1 Page 3 of 4 INITIATING CUE:

The CRS asks you about the status of Att. B of 1502.004, Control of Unit 1 Refueling. A license candidate has just completed Att. B and gives it to you for review. Determine if refueling requirements have been met and what actions need to be taken if they have not been met.

CRITICAL ELEMENTS (C) 2 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSA T

1. Review the completed Att. B of Examinee reviewed the attachment.

1502.004.

2. Identify errors. Examinee identified the following:

(C)

1. VEF-15 FAN ON box not checked.

2. N/A entered under RECORD FLOWRATE for VEF-15.

3. IAW Note 3 TRM 3.6.1Condition A should be entered.

4. IAW Note 3 fuel movement should cease OR the remaining steps in this standard should be taken:

RB purge should be isolated.

a tritium sample of refueling canal water obtained.

Shifty tritium sampling of RB atmosphere commenced.

END

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-REFUL1 Page 4 of 4 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:

A refueling outage is in progress.

Fuel handling is in progress.

INITIATING CUE:

The CRS asks you about the status of Att. B of 1502.004, Control of Unit 1 Refueling. A license candidate has just completed Att. B and gives it to you for review. Determine if refueling requirements have been met and what actions need to be taken if they have not been met.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RAD1 Page 1 of 4 UNIT: ______1_______ REV # _____2_________ DATE: ______________________________

TUOI NUMBER:_A1JPM-RO-RAD1__________________

SYSTEM/DUTY AREA:_ADMINISTRATIVE TOPIC-RADIATION CONTROL_________________________

TASK:_ABILITY TO CONTROL RADIATION RELEASES.________________________________________

JTA#:_ANO1-WCO-CZ-NORM-11________________

KA VALUE RO:___2.7 SRO:__3.2_____ KA

REFERENCE:

__2.3.11_________________

APPROVED FOR ADMINISTRATION TO: RO:____X___ SRO:________

TASK LOCATION: INSIDE CR:____X____ OUTSIDE CR:_________ BOTH:________

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE:_______________ SIMULATOR:___PERFORM_______ LAB:__________________

POSITION EVALUATED: RO:_____X_____ SRO:____N/A_______

ACTUAL TESTING ENVIRONMENT: SIMULATOR:____X_____ PLANT SITE:__________ LAB:________

TESTING METHOD: SIMULATE:____X____ PERFORM:___________

APPROXIMATE COMPLETION TIME IN MINUTES:__15 MINUTES________________________________

REFERENCE(S):__ 1104.020, Chg. 042-00-0, P-47B Pump Differential Pressure versus Flow Rate graph EXAMINEE'S NAME:________________________________ SSN ______-_____-____________

EVALUATOR'S NAME:__________________________________________________________________

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY:________________ UNSATISFACTORY:_________________

PERFORMANCE CHECKLIST COMMENTS:

____________ Start Time ____________ Stop Time ____________ Total Time SIGNED ________________________________ DATE: _______________________

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RAD1 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the "Briefing Checklist - System Walkthrough" portion of 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: Plant is shutdown for a Refueling Outage. Circulating Water Pump P-3A in service. ALL other Circ Water Pumps are OOS for maintenance. Discharge flow to flume indicator (FI-4642) is INOPERABLE and OOS. T-16B TWMT release is in progress. Maximum allowable flow rate for the release from Preliminary Report is 90 gpm. WCO reports CV-4642, CZ Discharge to Flume Flow Control Valve, is throttled open. WCO reports that P-47B, Treated Waste Monitoring Pump, parameters after establishing flow through CV-4642: Suction Pressure = 10 psig, Discharge Pressure = 38 psig.

TASK STANDARD: Candidate estimates release flow rate between 75 to 85 gpm and is within the allowable flow rate specified in the Preliminary Report.

TASK PERFORMANCE AIDS: 1104.020, Att. B2, Offsite Dose Calculation Manual (ODCM) and P-47B Pump Differential Pressure versus Flow Rate graph.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RAD1 Page 3 of 4 INITIATING CUE:

The CRS directs you to perform step 4.15.1 of 1104.020 Att. B2 Treated Waste Monitor Tank (TWMT) T-16B Liquid Release Permit and report if the release flow rate is within the allowable limit.

CRITICAL ELEMENTS (C):___3, 5_______

(c) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT Examiner Cue: Provide Candidate with copy of partially completed 1104.020, ATT B2.

1. Candidate performs a review of Performed review of T-16B Liquid ATT B TWMT Release Permit. Release Permit.

2. Perform step 4.15.1.A FI-4642 Recognized actions for inoperable inoperable actions. flow indicator contained in ODCM App. 1 Table 2.1-1.

3. Determine required actions for Utilized procedure to ensure conducting release with FI-4642 compliance with ODCM App. 1 Table C _____ _____ _____

inoperable. 2.1-1 Action 2. Determined release flow rate required to be estimated at least once every four hours utilizing pump curves.

Note: Candidate should discuss options available to obtain pump curve data which may include any of the following:

1) Contacting System Engineer 2) Reference Pump Technical Manual.

Examiner Cue: Provide Candidate with copy of P-47B Pump Curve upon request.

4. Obtain pump curve data to estimate Candidate obtained pump curve data.

release flow rate.

Note: Pump Suction and Discharge pressure are given in Initial Task Conditions.

5. Determine pump flow rate based on Candidate calculated pump pump differential pressure. differential pressure and estimates a C _____ _____ _____

flow rate of 70 to 80 gpm using pump curve.

6. Report that flow is within allowable Candidate reported to CRS that flow limit. is within allowable limit.

END

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RAD1 Page 4 of 4 JPM INITIAL TASK CONDITIONS:

Plant is shutdown for a Refueling Outage.

Circulating Water Pump P-3A in service. ALL other Circ Water Pumps are OOS for maintenance.

Discharge flow to flume indicator (FI-4642) is INOPERABLE and OOS.

T-16B TWMT release is in progress.

Maximum allowable flow rate for the release from Preliminary Report is 90 gpm.

WCO reports CV-4642, CZ Discharge to Flume Flow Control Valve, is throttled open.

WCO reports that P-47B, Treated Waste Monitoring Pump, parameters after establishing flow through CV-4642:

Suction Pressure = 10 psig Discharge Pressure = 38 psig INITIATING CUE:

The CRS directs you to perform step 4.15.1 of 1104.020 Att. B2 Treated Waste Monitor Tank (TWMT) T-16B Liquid Release Permit and report if the release flow rate is within the allowable limit.

Treated Waste Monitor Pump P-47B 60 Pump Differential Pressure (PSID) 55 50 45 40 35 30 25 20 15 10 5

0 0 20 40 60 80 100 120 140 160 Flow - GPM (5 GPM increments)

ES-301 Administrative Topics Outline Form ES-301-1 Facility: ANO-1 Date of Examination: 9-12-05 Examination Level (circle one): RO / SRO Operating Test Number: 1 Type Administrative Topic Describe activity to be performed Code*

(see note)

Conduct of Operations Ability to apply technical specifications for a system.

N/S New admin JPM A1JPM-SRO-TS1 2.1.12 (Imp 4.0)

Ability to maintain primary and secondary plant Conduct of Operations N/S chemistry within allowable limits.

2.1.34 New admin JPM A1JPM-SRO-CHEM1 (Imp2.9)

Equipment Control Knowledge of the process for controlling temporary N/S changes.

2.2.11 New admin JPM A1JPM-SRO-TALT2 (Imp 3.4)

Radiation Control Ability to perform procedures to reduce excessive M/S levels of radiation and guard against personnel 2.3.10 exposure.

(Imp 3.3) Modified A1JPM-SRO-RC22 Emergency Plan Knowledge of the emergency plan.

N/S New admin JPM A1JPM-SRO-EAL9.

2.4.29 (Imp 4.0)

NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when all 5 are required.

Type Codes & Criteria: (C)ontrol room (D)irect from bank ( 3 for ROs; 4 for SROs)

(N)ew or (M)odified from bank ( 1 (P)revious ( 1; randomly selected)

(S)imulator ES-301, Page 22 of 27

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TS1 Page 1 of 4 UNIT: 1 REV # 0 DATE: ______________________________

TUOI NUMBER: A1JPM-SRO-TS1 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - CONDUCT OF OPERATIONS TASK: Apply technical specifications for a system.

JTA#: ANO-SRO-ADMIN-NORM-22 KA VALUE RO: 2.9 SRO: 4.0 KA

REFERENCE:

2.1.12 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR:_________ BOTH:________

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE:_______________ SIMULATOR: PERFORM LAB:_________________

POSITION EVALUATED: RO: N/A SRO: X ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE:__________ LAB:________

TESTING METHOD: SIMULATE:_________ PERFORM:___________

APPROXIMATE COMPLETION TIME IN MINUTES: 30 MINUTES REFERENCE(S): Unit One Technical Specifications; 1104.036 EXAMINEE'S NAME:________________________________ SSN ______-_____-____________

EVALUATOR'S NAME:__________________________________________________________________

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY:________________ UNSATISFACTORY:_________________

PERFORMANCE CHECKLIST COMMENTS:

____________ Start Time ____________ Stop Time ____________ Total Time SIGNED ________________________________ DATE: _______________________

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TS1 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: The plant had been operating at 100% for 100 days. DH pump P-34A is tagged out to replace a leaking seal. The monthly surveillance for DG2 has begun to ensure it is completed within the requirements of the surveillance schedule.

TASK STANDARD: Examinee correctly recognizes that Tech Spec LCO SR 3.8.1.1 , 3.8.1 condition B is applicable, LCO 3.8.1 condition B.2 declare the DH pump P-34B inoperable due to inoperable emergency power supply, LCO 3.5.2 condition C applicable due to both DH pumps inoperable. 3.5.2 condition C is also applicable, and LCO 3.0.3 must be entered.

TASK PERFORMANCE AIDS: 1104.036; Technical Specifications

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TS1 Page 3 of 4 INITIATING CUE:

The CBOT has just performed, Supplement 2, DG2 Monthly Test, of 1104.036 through step 2.9.4, he discontinued the test per step 2.9.5, and has given you, the CRS, the supplement for review.

CRITICAL ELEMENTS (C) 4 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSA T

1. Review supplement. Reviewed supplement.

2. Perform step 3.2. Performed the following:

Immediately notified Shift Manager.

Declared DG2 inoperable.

Verified a Condition Report initiated.

Initiated corrective action.

3. Per step 3.2, reference Tech Specs. Referenced Tech Specs.

(C) 4. Determine applicable Tech Specs Determined the following:

and required actions.

SR 3.8.1.1

LCO 3.8.1 condition B applicable _____ _____ _____

due to inoperable DG2.

LCO 3.8.1 condition B.2, declare the DH pump P-34B inoperable due to inoperable emergency power supply.

LCO 3.5.2 condition C applicable due to both DH pumps inoperable.

LCO 3.0.3 would be entered.

END

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TS1 Page 4 of 4 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:

The plant had been operating at 100% for 100 days.

DH pump P-34A is tagged out to replace a leaking seal.

The monthly surveillance for DG2 has begun to ensure it is completed within the requirements of the surveillance schedule.

INITIATING CUE:

The CBOT has just performed, Supplement 2, DG2 Monthly Test, of 1104.036 through step 2.9.4, he discontinued the test per step 2.9.5, and has given you, the CRS, the supplement for review.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-CHEM1 Page 1 of 4 UNIT: 1 REV # 0 DATE: ______________________________

TUOI NUMBER: A1JPM-SRO-CHEM1 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - CONDUCT OF OPERATIONS TASK: Respond to secondary chemistry parameter out of specification JTA#: ANO-SM-ADMIN-NORM-165 KA VALUE RO: 2.3 SRO: 2.9 KA

REFERENCE:

2.1.34 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR:_________ BOTH:________

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE:_______________ SIMULATOR: PERFORM LAB:_________________

POSITION EVALUATED: RO: N/A SRO: X ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE:__________ LAB:________

TESTING METHOD: SIMULATE:_________ PERFORM:___________

APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1000.042 Steam Generator Water Chemistry Monitoring - Unit One EXAMINEE'S NAME:________________________________ SSN ______-_____-____________

EVALUATOR'S NAME:__________________________________________________________________

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY:________________ UNSATISFACTORY:_________________

PERFORMANCE CHECKLIST COMMENTS:

____________ Start Time ____________ Stop Time ____________ Total Time SIGNED ________________________________ DATE: _______________________

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-CHEM1 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: The plant has been operating at 100% for 215 days. The shift chemist has just arrived in your office and has given you, the Shift Manager, form 1000.042A to review.

TASK STANDARD: Examinee correctly recognizes that the threshold for Action Level 3 has been exceeded and the plant should be shutdown within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

TASK PERFORMANCE AIDS: 1000.042

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-CHEM1 Page 3 of 4 INITIATING CUE:

As Shift Manager, review the 1000.042A form for out of specification Feedwater chlorides.

CRITICAL ELEMENTS (C) 3 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSA T

NOTE: Inform trainee that continuous monitor readings correspond with sample results.

1. Compare results of confirmatory Requested readings of continuous analyses to readings from monitors to compare with lab continuous monitors. analyses results on 1000.042A. _____ _____ _____

NOTE: Inform trainee that Chemistry suspects a bad polisher to be the source of the chlorides.

2. Identify and isolate sources of Inquired as to results of searches for impurity ingress. source of chloride in-leakage. _____ _____ _____

(C) 3. Refer to Attachment 3 1000.042. Referred to Att. 3 and determined that Action Level 2 as shown on the form is incorrect and that Action Level 3 _____ _____ _____

had been exceeded. Action Level 3 requires the plant to be shutdown as quickly as possible (typically within six hours) instead of the 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months allowed for Action Level 2.

END

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-CHEM1 Page 4 of 4 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:

The plant had been operating at 100% for 215 days.

The shift chemist has just arrived in your office and has given you, the Shift Manager, form 1000.042A to review.

INITIATING CUE:

As Shift Manager, review the 1000.042A form for out of specification Feedwater chlorides.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TALT2 Page 1 of 4 UNIT: 1 REV # 0 DATE: ______________________________

TUOI NUMBER: A1JPM-SRO-TALT2 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - EQUIPMENT CONTROL TASK: QUARTERLY CHECK OF TEMPORARY ALTERATIONS JTA#: ANO-SRO-ADMIN-NORM-89 KA VALUE RO: 2.8 SRO: 3.4 KA

REFERENCE:

2.2.11 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR:_________ BOTH:____X____

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE:___PERFORM __ SIMULATOR: _______ LAB:__________________

POSITION EVALUATED: RO:____ __ SRO:___________

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE:__________ LAB:________

TESTING METHOD: SIMULATE:_________ PERFORM:___________

APPROXIMATE COMPLETION TIME IN MINUTES: 20 MINUTES REFERENCE(S): 1000.028 Chg. 024-00-0 EXAMINEE'S NAME:________________________________ SSN ______-_____-____________

EVALUATOR'S NAME:__________________________________________________________________

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY:________________ UNSATISFACTORY:_________________

PERFORMANCE CHECKLIST COMMENTS:

____________ Start Time ____________ Stop Time ____________ Total Time SIGNED ________________________________ DATE: _______________________

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TALT2 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: The plant is in Mode 3 for turbine repairs. All Temporary Alterations_tags are in place.

TASK STANDARD: The examinee has reviewed the attached temporary alteration and______

identified at least 2 administrative errors.

TASK PERFORMANCE AIDS: Temporary Alteration with 3 errors.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TALT2 Page 3 of 4 INITIATING CUE:

The Shift Manager directs you to conduct a Quarterly Review of Temporary Alteration 03-1-009 per 1000.028. You have in hand the package as found in the Control Room file. Identify at least 2 administrative errors.

CRITICAL ELEMENTS (C) 2 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSA T

1. Review Temporary Alteration Examinee reviewed Temporary Package 03-1-009. Alteration Package 03-1-009.

(C) 2. Identify administrative errors in Examinee identified at least 2 of 3 Temporary Alteration Package errors on Temporary Alteration 03-1-009. Package 03-1-009:

Improper mode (only Mode 1 checked, all modes should be checked)

Installation authorization not signed

1000.028E Integrated Drawing list is missing does not agree with 1000.028G, Affected Drawing list in TAP. E-13 sh. 1 and E-111 sh.

3 are not on 1000.028E.

END

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TALT2 Page 4 of 4 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:

The plant is in Mode 3 for turbine repairs.

All Temporary Alterations tags are in place.

INITIATING CUE:

The Shift Manager directs you to conduct a Quarterly Review of Temporary Alteration 03-1-009 per 1000.028. You have in hand the package as found in the Control Room file. Identify at least 2 administrative errors.

PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE: PAGE: 22 of 38 1000.028 CONTROL OF TEMPORARY ALTERATIONS CHANGE: 024-00-0 E. Copies of the Temporary Alteration Package are forwarded to:

1. IF OSRC final review is required and has not been obtained, THEN forward original to OSRC promptly and file a copy in the Control Room.

2. Manager, Design Engineering (Affected Document List only).

3. Manager, System Engineering.

4. Control Room of other unit, if affected.

F. Document the verification by signing and dating the appropriate blocks on the Temporary Alteration Package, Form 1000.028A.

6.11.3 The SM/CRS shall ensure that the original Temporary Alteration Package is kept under the control of the respective Control Room after final OSRC approval is obtained.

6.11.4 Upon receipt of the post-installation copy of a Temporary Alteration Integrated Drawing List, the Manager, Design Engineering, shall ensure that drawings listed are identified in a site-wide manner such that persons using controlled copies of the drawings outside the Control Room may become aware of the existence of the Temporary Alterations.

6.12 AUDIT OF A TEMPORARY ALTERATION PACKAGE 6.12.1 Upon receipt of the post-installation copy of a Temporary Alteration Package, the Manager, System Engineering shall direct the Installation Engineer, or some other person who meets the requirements to be an Installation Engineer, to audit the original Temporary Alteration Package. This audit should be completed within 7 days of the installation of the Temporary Alteration Package.

6.13 PERIODIC REVIEW OF AN INSTALLED TEMPORARY ALTERATION 6.13.1 Control Room personnel should maintain cognizance of the temporary alteration log to ensure that they are aware of installed temporary alterations.

PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE: PAGE: 23 of 38 1000.028 CONTROL OF TEMPORARY ALTERATIONS CHANGE: 024-00-0 6.13.2 The Operations Manager for the affected unit shall ensure that the following checks are performed for each installed temporary alteration. Those temporary alterations which affect both units shall be checked by the unit which holds the original Temporary Alteration Package.

(P-7993, P-11247) A. Operations Quarterly checks:

1. Verify the alteration need is still temporary.

2. Mode requirements are properly met.

3. TA Tags are in place in accordance with the TA Tag Record Sheet (Form 1000.028B).

4. The Integrated Drawing List (Form 1000.028E) properly lists the drawings on the Affected Drawing List for each TAP. This will be indicated by initialing the Affected Drawing List in the appropriate blank.

5. The original TAP is complete and on file in the responsible Control Room.

6.13.3 The Operations Manager shall forward reports of these reviews to the System Engineering Manager.

(P-7993) 6.13.4 Prior to startup following a scheduled outage or a change in operating mode, the operations manager shall review installed temporary alterations to ensure that no temporary alterations are required to be removed and that the installed temporary alterations are still required.

6.13.5 The System Engineering Manager should ensure a physical check of accessible portions of Temporary Alterations is made quarterly, concurrent with the normal System Engineering walkdowns. The check should include verification of the following:

A. The temporary alteration is installed properly.

B. The temporary alteration is in good materiel condition.

C. The checks will note any problems and actions taken to maintain the temporary alteration. Temporary instrumentation will be checked to verify that required calibrations are current and will remain current until next quarterly review. The System Engineering Manager shall ensure that appropriate actions are taken to resolve the concerns.

D. Action has been initiated to eliminate the need for the Temporary Alteration.

TUOI NUMBER:

A1JPM-SRO-RC22 Page 1 of 4 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date: 3/15/2005 TUOI NUMBER: A1JPM-SRO-RC22 System/Duty Area: Administrative Topic-Radiation Control Task: Calculate Stay times for yourself and another operator JA# ANO-SRO-ADMIN-NORM-162 KA Value RO 2.6 SRO 3.3 KA Reference G 2.3.10 Approved For Administration To: RO SRO Task Location: Inside CR: Outside CR: Both:

Suggested Testing Environment And Method (Perform Or Simulate): Simulate Plant Site: Simulator: Perform Lab:

Position Evaluated: RO: SRO: X Actual Testing Environment: Simulator: Plant Site: Lab Testing Method: Simulate: Perform:

Approximate Completion Time In Minutes: 20 Minutes Reference(S): HP Survey Map of P36C, Pump Room 54.

Examinee's SSN:

Name:

Evaluator's Name:

The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:

Satisfactory: Unsatisfactory:

Performance Checklist Comments:

Start Time Stop Time Total Time Signed Date:

Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.

TUOI NUMBER:

A1JPM-SRO-RC22 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the Briefing Checklist - System Walkthrough portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS:

You are an operator with the plant at full power. A hot spot has developed on Makeup PUMP P36C. You and another operator will be working in the vicinity of the reduction gear assembly in order to flush the lines and reduce the hot spot radiation field.

Using the supplied survey map, determine the individual stay times for yourself AND the other operator without exceeding the annual administrative dose limit (Ignore dose received during transit). You have an accumulated annual Whole Body dose of 1750 mR (ANO records). The other operator has an accumulated annual Whole Body dose of 1650 mR (ANO records). No additional dose has been received at any other site.

Also, calculate stay times if the air in the pump room was contaminated with a level of 0.40 DAC (stochastic) assuming no respirators are used.

Calculations should be based on ANO Unit 1 Administrative dose limits. Provide answers with 3 significant figures (example 4.51 hours5.902778e-4 days 0.0142 hours 8.43254e-5 weeks 1.94055e-5 months ). Do not consider ALARA task requirements. Any required dose extensions have been processed and approved.

TASK STANDARD:

The examinee has correctly determined the stay times for himself and the other operator on the assignment.

TASK PERFORMANCE AIDS:

HP Survey map of P36C Pump Room, Room number 54.

SIMULATOR SETUP:

N/A

TUOI NUMBER:

A1JPM-SRO-RC22 Page 3 of 4 INITIATING CUE: Determine the Stay time for you and the other operator on the job. Also determine the stay time if the air in the pump room was contaminated with a level of 0.40 DAC (stochastic) assuming no respirators are used. Provide answers with 3 significant figures (example X.XX hours).

CRITICAL ELEMENTS (c): 1,2, and 3 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT C 1. Determine the HIGHEST general area dose rate in Examinee has determined the the area of the reduction gear assembly to be used HIGHEST general area dose rate ____ ____ ___

from the survey map. in the area of the reduction gear assembly to be used from the survey map of P36C pump room.

(75 mR/hr)

C 2. Determine Stay time (to 3 significant figures) with Examinee has determined that no airborne contamination for both operators. the stay time for him/her is 3.33 ____ ____ ___

hrs and the stay time for the other Key: Max dose at ANO1 is 2000 mR operator is 4.67 hrs plus or minus 0.01 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

OP1 has 1750mR, =>allowed dose 250mR OP2 has 1650mR, =>allowed dose 350mR 250mR = 3.33 hr, 350mR = 4.67 hr 75mR/hr 75mR/hr C 3. Determine Stay time( to 3 significant figures) WITH Examinee has determined that airborne contamination for both operators. the stay time for him/her is ____ ____ ___

3.29hrs and the stay time for the 1DAC = 2.5mR/hr => 0.40DAC =>1.0mR/hr other AO is 4.61 hrs plus or minus Total rate = 75mR/hr + 1.0mR/hr = 76mR/hr 0.01 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

250mR ___ = 3.29 hr 76mR/hr 350mR ___ = 4.61 hr 76mR/hr EXAMINERS CUE: This concludes the JPM.

END

TUOI NUMBER:

A1JPM-SRO-RC22 Page 4 of 4 EXAMINEES COPY INITIAL CONDITIONS:

You are an operator with the plant at full power. A hot spot has developed on Makeup PUMP P36C. You and another operator will be working in the vicinity of the reduction gear assembly in order to flush the lines and reduce the hot spot radiation field.

Using the supplied survey map, determine the individual stay times and another operator without exceeding the annual administrative dose limit (Ignore dose received during transit). You have an accumulated annual Whole Body dose of 1750 mR (ANO records). The other operator has an accumulated annual Whole Body dose of 1650 mR (ANO records). No additional dose has been received at any other site.

Also calculate stay times if the air in the pump room was contaminated with a level of 0.40 DAC (stochastic) assuming no respirators are used.

1 DAC = 1 ALI 1 ALI is assumed to accumulate over 2000 hrs 1 ALI = 5000 mR Calculations should be based on ANO Unit 1 Administrative dose limits. Provide answers with 3 significant figures (example X.XX hours). Do not consider ALARA task requirements. Any required dose extensions have been processed and approved.

See handout for definitions.

INITIATING CUE:

Determine the Stay time for you and the other operator on the job. Also determine stay time if the air in the pump room was contaminated with a level of 0.40 DAC (stochastic) assuming no respirators are used. Provide answers with 3 significant figures (example X.XX hours).

MAP NUMBER: 1A2-16 LOCATION: U1 AUX 335 EL. P36C PUMP ROOM, ROOM NUMBER 54 Smear Data Rx. % _100___________________

Date __09/01/2005____________

Time ___0000:00______________

DPM/ _100cm2 Aux building No. Activity

_1___ _20,000__ Dose Rate Inst. _HP-DR-170____

posted: RM,RWPR _2___ _30,000___

_3___ _60,000___ Cal Due Date __12/31/2005____

_4___ _10,000___

_____ __________ Dose Rate Inst. #2 _RM-065____

335 posted RA _____ __________ Cal Due Date __12/31/2005_

Count Inst. ____RO-705____

_____ __________ Cal Due Date _12/31/2005_____

400.0/150.0 HS

_____ __________ Bkg. _80__ cpm D/C ___10_____

_____ __________ Count Inst. #2 ____RO-708_____

Cal Due Date __12/31/2005____

50.0 _____ __________ Bkg. __90_ cpm D/C ___10______

75.0 1

_____ __________ Survey Frequency:

_____ __________ _____ Daily

_____ __________ _____ Bi-Weekly 1.0

_____ __________ __X_ Monthly 4 _____ __________

_____ Quarterly

_____ __________ _____ Job Coverage 2 _____ __________ _____ Other 3 _____ __________

0.4 _____ __________ _____________________________

55.0 _____ __________ RWP # _4005/1_

Surveyor:

--- _John Public_____ ___1234_

Alpha Smears Badge DPM/100cm2 RP Supervisor Review:

No. Activity

_____ __________ _Imma N. Charge_____________

All Radiation values are in mrem/hour unless otherwise noted. DANI # __011256______________

12.5 denotes gamma general area dose rates. _____ __________

Smear contamination values are in DPM/100 Sqcm unless otherwise noted. H. S. Denotes Hot Spot Readings _____ __________ Page 1 of __1____

12/13 Denotes Gamma Contact/Far reading (30 cm) Denotes smear location (100 sqcm.) _____ __________

12 Denotes contact dose rate (gamma) *12 B Denotes Beta Contact Dose Rate Denotes large area smear location _____ __________

Form to be retained for records _____ __________

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-EAL9 Page 1 of 4 UNIT: 1 REV # 0 DATE: ______________________________

TUOI NUMBER: A1JPM-SRO-EAL9 SYSTEM/DUTY AREA: ADMINISTRATIVE TOPIC - EMERGENCY PROCEDURES/PLAN TASK: TAKE EMERGENCY DIRECTION AND CONTROL JTA#: ANO-SM-EPLAN-EMERG-302 KA VALUE RO: 2.6 SRO: 4.0 KA

REFERENCE:

2.4.29 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR:_________ BOTH:________

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE:_______________ SIMULATOR: PERFORM LAB:________________

POSITION EVALUATED: RO: N/A SRO: X ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE:__________ LAB:________

TESTING METHOD: SIMULATE:_________ PERFORM:___________

APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1903.010 Chg. 037-03-0, 1903.011, Chg. 028-00-0 EXAMINEE'S NAME:________________________________ SSN ______-_____-____________

EVALUATOR'S NAME:__________________________________________________________________

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY:________________ UNSATISFACTORY:_________________

PERFORMANCE CHECKLIST COMMENTS:

____________ Start Time ____________ Stop Time ____________ Total Time SIGNED ________________________________ DATE: _______________________

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-EAL9 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: The following conditions exist:

Unit One reactor has tripped one hour ago. Reactor Building radiation levels are reading 190 R/hr. RP reports radiation levels are 2000 mR/hr from sample point SA-229. RB Sump level on L-1405 is steady at 60%. Aux.

Bldg. Sump level on L-4403 is rising. Dirty Waste Drain Tank T-20A/B levels are going up. SE calculates an RCS leak rate of 60 gpm. RDACS is indicating an offsite release is in progress.

TASK STANDARD: Examinee correctly classifies this event as a GE per EAL 1.7 and makes notifications to plant personnel per step 4 of 1903.011S.

TASK PERFORMANCE AIDS: 1903.010 Attachments 1 and 3, and 1903.011

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-EAL9 Page 3 of 4 INITIATING CUE:

For the given plant conditions, determine the applicable EAL classification and initiate notifications through step 4 of the applicable Shift Manager checklist in 1903.011.

CRITICAL ELEMENTS (C) 3, 5 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Compare event conditions with the Turned to Attachment 1 of 1903.010, Index of EALs, Attachment 1 of Index of EALs.

1903.010, Emergency Action Level _____ _____ _____

Classification.

2. Turn to appropriate EAL and Turned to a specific EAL in Safety compare EAL criteria with event System Function, Attachment 3 of _____ _____ _____

conditions. 1903.010.

(C) 3. Declare the emergency Declared or stated the event is a GE classification. based on EAL 1.7, Loss of or challenge to all three fission product _____ _____ _____

barriers (not required to be stated).

4. Initiate immediate notifications. Referred to 1903.011. _____ _____ _____

NOTE: Cue the examinee that the Unit 2 Shift Engineer is performing the initial notifications per 1903.011 after the examinee has stated that Unit 2 Shift Engineer (or control room communicator) has been requested.

(C) 5. Begin completion of form Began completion of form 1903.011S 1903.011S, GE Emergency GE Emergency Direction and Control Direction and Control Checklist for Checklist for Shift Manager.

Shift Manager.

Examinee should fill in the data on items 1 and 2. _____ _____ _____

Examinee should simulate (or state) direction of the SE to complete the initial notification.

6. Inform Control Room Staff of Informed Control Room Staff of GE. _____ _____ _____

Emergency Class declaration.

END

ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-EAL9 Page 4 of 4 EXAMINEES COPY JPM INITIAL TASK CONDITIONS:

Unit One reactor has tripped one hour ago.

Reactor Building radiation levels are reading 190 R/hr.

RP reports radiation levels are 2000 mR/hr from sample point SA-229.

RB Sump level on L-1405 is steady at 60%.

Aux. Bldg. Sump level on L-4403 is rising.

Dirty Waste Drain Tank T-20A/B levels are going up.

SE calculates an RCS leak rate of 60 gpm.

RDACS is indicating an offsite release is in progress.

INITIATING CUE:

For the given plant conditions, determine the applicable EAL classification and initiate notifications through step 4 of the applicable Shift Manager checklist in 1903.011.

PROC./WORK PLAN NO. PROCEDURE/WORK PLAN TITLE: PAGE: 25 of 130 1903.010 EMERGENCY ACTION LEVEL CLASSIFICATION CHANGE: 037-03-0 ATTACHMENT 3 UNIT 1 PRIMARY SYSTEM EVENTS

1.7 CONDITION

Loss of or challenge to all 3 Fission Product Barriers EMERGENCY CLASSIFICATION:

General Emergency MODES __All____

CRITERIA:

1. Either of the following conditions exist:

A. Fuel Cladding Failure (refer to section 4.10.1)

B. Challenge to Fuel Cladding (refer to section 4.11.1)

AND

2. Either of the following conditions exist:

A. RCS boundary failure (refer to section 4.10.2)

B. Challenge to RCS boundary (refer to section 4.11.2)

AND

3. Either of the following conditions exist:

A. Containment Integrity failure (refer to section 4.10.3)

B. Challenge to Containment Integrity (refer to section 4.11.3)

RELATED EALS: TAB Containment Radiation High/Very High 1 Core Melt 1 Radiological Effluents 5 Natural Events 8

PROC./WORK PLAN N

O. PROCEDURE

/WORK PLAN TITLE: PAGE: 29 of 58 1903.011 EMERGENCY RESPONSE/NOTIFICATIONS CHANGE: 028-00-0 ATTACHMENT 4 GENERAL EMERGENCY Upon declaration of a General Emergency, the person with the responsibility for Emergency Direction and Control shall:

Complete the appropriate Emergency Direction and Control Checklist indicated below for your position (i.e. SM, TSC Director, or EOF Director). Any steps that are not appropriate for the event may be marked 'Not Applicable' (N/A).

Issue appropriate offsite protective action recommendations.

Ensure that notifications are completed in accordance with the required time limits.

At the termination of the event, the Shift Manager/TSC Director/EOF Director should forward all forms and other pertinent documents to Emergency Planning.

Forms, used for General Emergency notification and response, are as follows:

Form 1903.011S, "GE Emergency Direction and Control Checklist, Shift Manager" (Shift Manager Only)

Form 1903.011T, "GE Emergency Direction and Control Checklist, TSC Director" (TSC Director Only)

Form 1903.011U, "GE Emergency Direction and Control Checklist, EOF Director" (EOF Director Only)

Electronic Form 1903.011-Y, "Emergency Class Initial Notification Message" Electronic Form 1903.011-Z, "Emergency Class Follow-up Notification Message" Attachment 5, Alternate ERO Notification Scheme Attachment 6, Protective Action Recommendations (PAR) for General Emergency

Page 30 of 58 Page 1 of 4 GE This form is intended to be used by the SHIFT MANAGER when a General Emergency has been declared and the Shift Manager has the responsibility for emergency Direction and Control.

1. General Emergency declared:

Unit_______ Time_______ Date_________

- EMERGENCY CLASSIFICATION / PLANT EVACUATION ANNOUNCEMENT SHOULD BE MADE WITHIN 15 MINUTES OF THE DECLARATION**

2. Conditions warranting declaration of a General Emergency:

EAL No._____

Description:

3. Notification Communicator 3.1 Single/Dual Unit Emergency

1. Activate CNS IF CNS already activated for an Alert or higher emergency class, THEN go to step 2 below.

Direct your units Shift Engineer to activate CNS in accordance with Attachment 9 of this procedure.

Use Section 8 of Attachment 9 if ERO is at risk due to site conditions (e.g. security event, toxic gas release, major onsite fire, etc). ERO will respond to the Alternate EOF.

Use Section 1 of Attachment 9 for normal ERO callout.

2. Direct the opposite units Shift Engineer to perform notifications using Form 1903.011-Y, "Emergency Class Initial Notification Message."

3.2 Additional Notification Communicator is Available

1. IF a Notification Communicator is available, THEN request the Notification Communicator to perform notifications in accordance with Form 1903.011-Y, "Emergency Class Initial Notification Message."

4. Inform the Control Room staff of the Emergency Class declaration.

FORM TITLE: FORM NO. REV.

GE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011S 028-00-0 SHIFT MANAGER

Page 31 of 58 Page 2 of 4

5. Has a plant evacuation been performed, NO - GO TO Step 6 YES - THEN perform the following:

A. Dial 197 B. Make the following announcement:

"Attention all personnel. Attention all personnel. A General Emergency has been declared on Unit ___(One/Two). Emergency response personnel report to your designated assembly areas."

C. Dial 197 and repeat the above announcement.

D. Repeat the above announcement using the EOF public address system by dialing 199 and pausing approximately 15 seconds before making the announcement.

E. GO TO step 15.

Plant Evacuation Section

6. Determine the appropriate evacuation routes:

6.1 DOES a radiological or toxic gas release exist or is a release suspected, which is originating from the plant?

YES - THEN determine the available routes from the chart below using wind direction.

IF wind direction is From: THEN use Evacuation Routes 0 to 100 degrees 1 and 2 101 to 220 degrees 1 221 to 359 degrees 2 NO - THEN use routes 1 and/or 2.

6.2 Check the appropriate routes in the plant announcement, step 10 below.

7. Determine any areas of the plant to avoid during evacuation and/or special protective measures to be taken by plant evacuees. List these instructions in plant announcement Step 10 below.

8. Direct Security to perform the following (ext. 3388, 3108 or 3109):

8.1 Use manual scanning to expedite evacuation, if necessary.

8.2 Perform initial accountability by ___________ (Time)

(30 minutes from GE declaration)

FORM TITLE: FORM NO. REV.

GE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011S 028-00-0 SHIFT MANAGER

Page 32 of 58 Page 3 of 4

9. Contact Radiation Protection (CA1 - 5166 or CA2 - 3018):

9.1 Request Health Physics coverage at the plant exit portal monitors.

9.2 Instruct Health Physics personnel at the controlled access exit point to relax decontamination and radiation protection measures as necessary in order to expedite evacuation of the controlled access area.

10. [Make the following announcement using the plant paging system (dial 197):

"Attention all personnel. Attention all personnel. A General Emergency has been declared on Unit ___(One/Two). Emergency response and emergency standby personnel report to your designated assembly areas and perform initial accountability. All other personnel evacuate the plant using evacuation route(s) 1 2 and proceed to the Atkins Emergency Worker Center."

If necessary, include in the announcement any plant areas to avoid, or special protective actions to be taken by plant evacuees:

10.1 Sound the evacuation alarm for approximately 10 seconds.

10.2 Repeat the announcement at least 2 times, alternating the announcement with the plant evacuation alarm.]

11. Make the following announcement using the EOF public address system (dial 199 and pause approximately 15 seconds).

"Attention all personnel. Attention all personnel. A General Emergency has been declared on Unit ___(One/Two). Emergency response personnel report to your designated assembly areas."

12. Instruct all Control Room personnel (operators, chemists, RP, etc.) to log into the designated security card reader using "0000".

13. Instruct both units' operators in the field to log into the nearest security card reader using "0000" and log onto the emergency RWP.

14. Inform the opposite unit Control Room personnel to log into the designated security card reader using "0000".

FORM TITLE: FORM NO. REV.

GE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011S 028-00-0 SHIFT MANAGER

Page 33 of 58 Page 4 of 4

15. Has an exclusion area evacuation been performed?

YES - GO TO Step 16.

NO - THEN perform the following:

Request that the U.S. Army Corps of Engineers (telephone number located in Emergency Telephone Directory) control boat access to the portions of Lake Dardanelle within the exclusion area.

Direct Security to evacuate the Generation Support Building (GSB) and all buildings outside the security fence but within the exclusion area.

Plant Evacuation Section Ends

16. Determine the appropriate Protective Action Recommendation using Attachment 6, "Protective Action Recommendations (PAR) for General Emergency".

PAR No. __________

Review PAR criteria every 15 minutes. Notify within 15 minutes the NRC, State and local government of PAR changes in accordance with Form 1903.011-Y, "Emergency Class Initial Notification Message."

17. Direct Chemistry personnel (Initial Dose Assessor) to the Control Room to implement procedure 1904.002, "Offsite Dose Projection - RDACS Computer Method".

18. IF an approach route to the plant site should be avoided, THEN instruct Security to direct incoming traffic. (Examples of this include security situations in which onsite/offsite personnel are directed to the EOF, radiological releases which prohibit entry to the site via secondary guard station, etc.)

Performed by:________________________________________

Shift Manager FORM TITLE: FORM NO. REV.

GE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011S 028-00-0 SHIFT MANAGER

ES-301 Control Room / in Plant Systems Outline Form ES-301-2 Facility: _ANO-1______________ Date of Examination: _ 9/12/2005 ____

Exam Level (circle one): RO / SRO(I) / SRO(U) Operating Test No.: ___One________

Control Room Systems@ ( 8 for RO; 7 for SRO-I; 2 or 3 for SRO- U)

System / JPM Title Type Code* Safety Function

a. A1JPM-RO-EOP22, Perform Reactor Trip Immediate Actions A/M/S 1 007 EK3.01 (RO 4.0/SRO 4.6) Reactivity

b. A1JPM-RO-LTOP1, Establish LTOP protection during cool down of RCS D/L/S 3 002 K4.10 (RO 4.2/SRO 4.4) Reactor Pressure Control

c. A1JPM-RO-RCP05, Shutdown of P-32C and P-32D after Decay Heat in service D/L/S 4 003 A4.03 (RO 2.8/SRO 2.5) Reactor Heat Removal (Primary)

d. A1JPM-RO-EOP16, Perform actions required to correct overcooling of the RCS A/D/S 4 039 A2.04 (RO 3.4/SRO 3.7) Reactor Heat Removal (Secondary)

e. A1JPM-RO-HYD03, Place Hydrogen Recombiner M-55B in operation C/D/L/S 5 028 A4.01 (RO 4.0/SRO 4.0) Containment Integrity

f. A1JPM-RO-EDO08, Shift buses A1, A2, H1, H2 from SU#1 to Unit Aux A/D/S 6 062 A4.07 (RO 3.1/SRO 3.1) Electrical

g. A1JPM-RO-ARM01, Respond to Area Rad Monitor alarm C/N/S 7 072 A4.01 (RO 3.0/SRO 3.3) Instrumentation

h. A1JPM-RO-AOP28, Respond to lo-lo Instrument Air pressure D/S 8 065 AK3.08 (RO 3.7/SRO 3.9) Plant Service Systems In- Plant Systems@ ( 3 for RO; 3 for SRO-I; 3 or 2 for SRO- U)

i. A1JPM-RO-CA01, Borate via alternate path bypassing batch controller N/R 1 004 K6.13 (RO 3.1/SRO 3.3) Reactivity

j. A1JPM-RO-EFW02, Manually control P-7A at turbine D/E/R 4 061 A2.05 (RO 3.1/SRO 3.4) Reactor Heat Removal (Secondary)

k. A1JPM-RO-EDO30, Place battery charger D-03B in service A/D/P 6 2.1.30 (RO 3.9/SRO 3.4) Electrical

@ All control room (and in-plant) systems must be different and serve different safety functions; Type Codes Criteria for RO /SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)direct from bank 9 / 8 / 4 (E)mergency or abnormal in-plant 1 / 1 / 1 (L)ow-Power 1 / 1 / 1 (N)ew or (M)odified from bank including 1(A) 2 / 2 / 1 (P)revious 2 Exams 3 / 3 / 2 (randomly selected)

(R)CA 1 / 1 / 1 (S)imulator ES-301, Page 23 of 27

ES-301 Control Room / in Plant Systems Outline Form ES-301-2 Facility: _ANO-1______________ Date of Examination: _ 9/12/2005 ____

Exam Level (circle one): RO / SRO(I) / SRO(U) Operating Test No.: ___One________

Control Room Systems@ ( 8 for RO; 7 for SRO-I; 2 or 3 for SRO- U)

System / JPM Title Type Code* Safety Function

a. A1JPM-RO-EOP22, Perform Reactor Trip Immediate Actions A/M/S 1 007 EK3.01 (RO 4.0/SRO 4.6) Reactivity

b. A1JPM-RO-LTOP1, Establish LTOP protection during cool down of RCS D/L/S 3 002 K4.10 (RO 4.2/SRO 4.4) Reactor Pressure Control

c. A1JPM-RO-RCP05, Shutdown of P-32C and P-32D after Decay Heat in service D/L/S 4 003 A4.03 (RO 2.8/SRO 2.5) Reactor Heat Removal (Primary)

d. A1JPM-RO-EOP16, Perform actions required to correct overcooling of the RCS A/D/S 4 039 A2.04 (RO 3.4/SRO 3.7) Reactor Heat Removal (Secondary)

e. A1JPM-RO-HYD03, Place Hydrogen Recombiner M-55B in operation C/D/L/S 5 028 A4.01 (RO 4.0/SRO 4.0) Containment Integrity

f. A1JPM-RO-EDO08, Shift buses A1, A2, H1, H2 from SU#1 to Unit Aux A/D/S 6 062 A4.07 (RO 3.1/SRO 3.1) Electrical

g. A1JPM-RO-ARM01, Respond to Area Rad Monitor alarm C/N/S 7 072 A4.01 (RO 3.0/SRO 3.3) Instrumentation h.

In- Plant Systems@ ( 3 for RO; 3 for SRO-I; 3 or 2 for SRO- U)

i. A1JPM-RO-CA01, Borate via alternate path bypassing batch controller N/R 1 004 K6.13 (RO 3.1/SRO 3.3) Reactivity

j. A1JPM-RO-EFW02, Manually control P-7A at turbine D/E/R 4 061 A2.05 (RO 3.1/SRO 3.4) Reactor Heat Removal (Secondary)

k. A1JPM-RO-EDO30, Place battery charger D-03B in service A/D/P 6 2.1.30 (RO 3.9/SRO 3.4) Electrical

@ All control room (and in-plant) systems must be different and serve different safety functions; Type Codes Criteria for RO /SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)direct from bank 9 / 8 / 4 (E)mergency or abnormal in-plant 1 / 1 / 1 (L)ow-Power 1 / 1 / 1 (N)ew or (M)odified from bank including 1(A) 2 / 2 / 1 (P)revious 2 Exams 3 / 3 / 2 (randomly selected)

(R)CA 1 / 1 / 1 (S)imulator ES-301, Page 23 of 27

ES-301 Control Room / in Plant Systems Outline Form ES-301-2 Facility: _ANO-1______________ Date of Examination: _ 9/12/2005 ____

Exam Level (circle one): RO / SRO(I) / SRO(U) Operating Test No.: ___One________

Control Room Systems@ ( 8 for RO; 7 for SRO-I; 2 or 3 for SRO- U)

System / JPM Title Type Code* Safety Function

a. A1JPM-RO-EOP22, Perform Reactor Trip Immediate Actions A/M/S 1 007 EK3.01 (RO 4.0/SRO 4.6) Reactivity

b. A1JPM-RO-LTOP1, Establish LTOP protection during cool down of RCS D/L/S 3 002 K4.10 (RO 4.2/SRO 4.4) Reactor Pressure Control C/N/S 7

c. A1JPM-RO-ARM01, Respond to Area Rad Monitor alarm 072 A4.01 (RO 3.0/SRO 3.3) Instrumentation d.

e.

f.

g.

h.

In- Plant Systems@ ( 3 for RO; 3 for SRO-I; 3 or 2 for SRO- U)

i. A1JPM-RO-EFW02, Manually control P-7A at turbine D/E/R 4 061 A2.05 (RO 3.1/SRO 3.4) Reactor Heat Removal (Secondary)

j. A1JPM-RO-EDO30, Place battery charger D-03B in service A/D/P 6 2.1.30 (RO 3.9/SRO 3.4) Electrical k.

@ All control room (and in-plant) systems must be different and serve different safety functions; Type Codes Criteria for RO /SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)direct from bank 9 / 8 / 4 (E)mergency or abnormal in-plant 1 / 1 / 1 (L)ow-Power 1 / 1 / 1 (N)ew or (M)odified from bank including 1(A) 2 / 2 / 1 (P)revious 2 Exams 3 / 3 / 2 (randomly selected)

(R)CA 1 / 1 / 1 (S)imulator ES-301, Page 23 of 27

Appendix D Scenario 1 Form ES-D-1 Facility: ANO-1 Scenario No.: 1 Op-Test No.:2005-1 NEW Examiners: Operators:

Initial Conditions: IC 101 70% power holding for the start of P8B (2nd heater drain pump)

Power escalation to 100% in progress following maintenance to the A MFW pump.

Idle condensate pump handswitch is in P-T-L.

Turnover:

70% power holding for the start of P8B (2nd heater drain pump). Heater Drain Pump, P8A has just been placed in service per 1106.016, section 16.0 through 16.19. Step 16.20 is ready to be performed and P8B placed in service. All preparations for the start of P8B have been completed. Condensate Pump, P2A, is in P-T-L per the procedure and the SG/RX Demand H/A station is in AUTO.

Power escalation to 100% in progress following maintenance to the A MFW pump.

Event Malf. No. Event Event No. Type* Description 1 N/A N (CBOT) Start a heater drain pump during power escalation 2 N/A R (CBOR) Power escalation toward 100% following maintenance to main Feedwater pump and after Heater Drain Pumps in service.

3 TR565 I (CBOR) RCS Thot slowly fails low Ramp=4 Min.

4 N/A N (CBOR) Place the ICS in AUTO.

5 RX604 C (CBOT) False increasing pulser signal to EHC causes 30%/min. Turbine Generator to raise load.

6 ED191 C (CBOT) Loss of non vital bus B3 7 ED183 M (All) Random electrical grid upsets result in loss of offsite power. Reactor trip. Degraded Power.

8 IRF B6231 C (CBOT) EDG #2 service water valve (CV3807) breaker trips IOR DO_HS3807G during opening causing minimal flow to the EDG for OFF cooling.

IOR DO_HS3807R OFF 9 DI_A_MSLI_1A False C (CBOR) All MSLI pushbuttons on the EFIC Remote Switch DI_A_MSLI_1B False Matrix fail to manually actuate the MSLI function DI_A_MSLI_2A False requiring alternative effort for performing function.

DI_A_MSLI_2B False DI_B_MSLI_1A False DI_B_MSLI_1B False DI_B_MSLI_2A False DI_B_MSLI_2B False

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 13

Appendix D Scenario 1 Form ES-D-1 Scenario #1 Objectives

1) Evaluate individual response to input signal failures to the Integrated Control System

2) Evaluate individual response to electrical system abnormal conditions

3) Evaluate individual response to a loss of offsite electrical power

4) Evaluate individual ability to start and control components of the feed and condensate system

5) Evaluate individual ability to perform a power escalation in accordance with plant procedures

6) Evaluate individual ability to recognize abnormal conditions associated with automatically actuated systems and components

7) Evaluate individual response to failure of actuation function associated with the Main Steam Line Isolation portion of EFIC SCENARIO #1 NARRATIVE The scenario begins with a power escalation to 100% in progress following maintenance to the A Main Feedwater pump. Power has been stabilized at ~70% to place the heater drain pumps in service to provide sufficient feedwater pump suction pressure to continue the power rise to 100%. The crew will place the second heater drain pump in service and begin the power escalation.

As power is raised toward ~80% power, an RCS hot leg temperature transmitter, that is providing input to the Integrated Control System, fails low. This failure, being a slow failure, and therefore the Smart Automatic Signal Selector system will not select the redundant instrument, causes a plant transient that will include control rods to withdraw and feedwater flow to be lowered. The crew is expected to intervene and stop the transient by placing the ICS in Manual mode and correct the affected plant parameters to stabilize the plant. Once stable, the crew will select the redundant (good) instrument to provide input to the ICS and perform the normal operation of placing the ICS in Automatic mode.

When the ICS is placed in AUTO following the temperature transmitter failure, the Turbine will begin rising without a commanded signal. The crew should recognize the rising turbine load and lowering of the turbine header pressure and place the turbine in a manual mode, either OPER AUTO or Turbine Manual. Contacts to support organizations should begin to troubleshoot the turbine malfunction. The Turbine will remain in a manual mode at this time.

An internal breaker fault in the feeder breaker to the non-vital B3 bus will cause the breaker to trip, causing a loss of the non-vital B3 bus. The crew is expected to respond to the loss of B3 using Annunciator Corrective Actions and Abnormal Operating Procedure for Loss of Loadcenter. The crew will start redundant equipment as directed by the operating procedures and stabilize the plant.

Page 2 of 13

Appendix D Scenario 1 Form ES-D-1 SCENARIO #1 NARRATIVE (continued)

Due to random electrical grid upsets in the system, a loss of offsite power will occur. The Reactor will trip automatically and the crew will begin addressing the Reactor Trip and degraded power situation. Once the Reactor Trip immediate actions have been completed, the crew will transition to the Degraded Power procedure for guidance.

While verifying the proper operation of actuated components due to the degraded power, the discovery of the service water valve to the #2 EDG failure will require the crew to take action to restore service water to the EDG or stop the EDG to protect it from damage due to overheating.

During performance of actions required by the Degraded Power procedure, the crew will be prompted to actuate MSLI on both OTSGs to establish a vital island concept for the heat removal from the primary to the secondary. When the operator attempts to actuate the function from the normally utilized remote switch matrix, the matrix buttons fail to execute the command. The crew must take contingency action to establish the MSLI function. This may be accomplished by manual positioning of the affected components or actuation of the function from the EFIC cabinets in the back of the control room.

The scenario will be terminated when the plant is at a point where the crew is awaiting the return of offsite power or at the discretion of the lead evaluator.

Page 3 of 13

Appendix D Scenario 1 Form ES-D-1 Simulator Instructions for Scenario 1 Event Time Malf. No. Value/ Event No. Ramp Time Description 1 Upon shift N/A N/A Start a heater drain pump during power relief escalation T=0 2 P8B in N/A N/A Power escalation toward 100% following service maintenance to main Feedwater pump (T=15) and after Heater Drain Pumps in service.

3 Cued by IRF TR565 520 RCS Thot slowly fails low lead evaluator Ramp=240 4 Following N/A N/A Place the ICS in AUTO.

selection of good transmitter 5 When ICS RX604 30% False increasing pulser signal to EHC in AUTO causes Turbine Generator to raise load.

T=45 6 T=57 ED191 N/A Loss of non vital bus B3 7 T=67 Actuate Random electrical grid upsets result in Trigger 1 loss of offsite power. Reactor trip.

Degraded Power.

N/A ED183 8 T=67 Actuate EDG #2 service water valve (CV3807)

Trigger 1 breaker trips during opening causing IRF B6231 .05 minimal flow to the EDG for cooling.

IOR OFF DO_HS3807G IOR OFF DO_HS3807R 9 Pre-loaded DI_A_MSLI_1A False All MSLI pushbuttons on the EFIC This event DI_A_MSLI_1B False Remote Switch Matrix fail to manually will occur DI_A_MSLI_2A False actuate the MSLI function requiring when the DI_A_MSLI_2B False alternative effort for performing function.

crew DI_B_MSLI_1A False performs DI_B_MSLI_1B False step to actuate DI_B_MSLI_2A False MSLI DI_B_MSLI_2B False Page 4 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 1 Event

Description:

Start a heater drain pump during power escalation Time Position Applicants Actions or Behavior T=0 CRS Direct the crew to place the B Heater Drain Pump in service per 1106.016, Condensate, Feedwater, and Steam System Operation.

CBOT At panel C12, Start P8B.

CBOT Monitor Heater Drain Pump discharge flow on the plant computer.

CBOT Dispatch the Auxiliary Operator to gradually open the manual discharge valve for P8B, (CS-59B), approximately 5 turns.

IA NOTE: To open CS59B; IRF CS59B .35 60 CBOT Using the controller on C12 for CV2810, slowly throttle closed the associated Recirc Control Valve. Monitor drain tank level, P8B discharge flow, and main feedwater pump suction pressure, while slowly lowering T40B level.

CREW When discharge flow is approximately 0.5 X 106 lb/hr, verify K06-A8 (P8A/P8B FLOW LO) clears.

CBOT WHEN T-40 level ~111", THEN place Recirc Control Valve in AUTO.

CBOT Verify Recirc Control Valve maintains Heater Drain Tank level ~111" (~49%).

CBOT Coordinate with the Auxiliary Operator to complete the alignment per the procedure.

CBOT Return idle Condensate Pump, P-2, handswitch to normal-after-stop.

CBOT Close Low Level Condenser Sprays (CV-2907 and CV-2868) on C02.

Event Termination:

P8B in service with recirc valve in AUTO Page 5 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 2 Event

Description:

Power escalation toward 100% following maintenance to main Feedwater pump and after Heater Drain Pumps in service.

Time Position Applicants Actions or Behavior T=15 CRS Direct the crew to escalate power at the desired rate as established by applicable procedures, instructions, ODMIs, etc.

NOTE: The normal maneuvering rate for this situation would be 30%/Hr.

however due to the small failed fuel the unit is experiencing, Reactor Engineering has recommended a rate of 15%/Hr. to 90% power, and 5%/Hr. to 100% in accordance with the ODMI established for this condition.

CBOR Using the rate of change setpoint on C03, set the rate at the desired value.

(0.5 on the dial sets 30%/Hr.; 0.25 on the dial sets 15%/Hr.)

CBOR Using the toggle switch on the ULD station, set the load demand to ~800MW.

(This begins the power escalation to approximately 90% power.)

CBOR Monitor the plant parameters for proper response to power escalation. Verify rod index limits and Axial Power Imbalance limits are not exceeded.

CBOT Monitor the turbine generator to ensure it responds properly to the power escalation.

Event Termination:

Cued by Evaluator for next event Page 6 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 3 Event

Description:

RCS Thot slowly fails low Time Position Applicants Actions or Behavior Cued by CBOR Acknowledge and report annunciator alarm K07-B4, SASS Mismatch, is in Evaluator alarm.

CBOR Identify the SASS enable light for the loop B Thot instrument on C03 has gone out.

CBOR Identify a plant transient is in progress.

CRS Direct the CBOR to place ICS in MANUAL.

(At a minimum, the A and B feedwater loop demands and the Reactor Demand Hand/Auto stations should be placed in MANUAL)

CBOR Place the A and B feedwater loop demands and the Reactor Demand CT hand/auto stations in Manual and verify the transient stops. IF the control rods continue to move, place the Diamond Station in MANUAL.

CRS Direct the crew using Annunciator Corrective Action 1203.012F for the SASS Mismatch alarm.

CBOT Verify the signal from the non-selected instrument is a valid good signal on PMS.

CBOR When directed, select the opposite instrument for Loop B Thot on C03.

CBOR Verify the proper response to the selection of the good instrument.

CRS Direct the crew to slowly adjust control rods and feedwater to restore Tave back to the desired value.

CBOR Slowly adjust feedwater demand stations and control rods to return Tave to

~579°F.

Event Termination:

Next event Page 7 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 4 Event

Description:

Place the ICS in AUTO.

Time Position Applicants Actions or Behavior After good CRS Direct the crew to place the ICS in AUTO.

transmitter selected CBOR Establish the initial conditions of 1105.004, step 8.1.1.

(This may require placing the SG/RX Master to HAND)

CBOT Verify the turbine controls in INTEG CONTROL and controlling turbine header pressure at setpoint.

CBOR Check the FW loop demand measured variable setpoints on the carat. If not, adjust with the SG/RX Master and/or the T-cold H/A station.

CBOR Check Tave at setpoint or adjust in accordance with the procedure.

CBOR Check Reactor Demand H/A station measured variable on the carat.

CBOR Check SG/RX Master H/A station position and measured variable are approximately equal.

CBOR With the above stations aligned, place them in AUTO in the following sequence:

A. Rod Controller (Diamond Panel), if applicable B. Reactor Demand C. Feedwater Loop Demands D. Load Ratio T-cold E. SG/RX Master Event Termination:

When the plant is stable with ICS in AUTO OR Next event Page 8 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 5 Event

Description:

False increasing pulser signal to EHC causes Turbine Generator to raise load.

Time Position Applicants Actions or Behavior T=45 CBOT Recognize and report the turbine reference and setter signals are rising.

CBOR Report the turbine header pressure is lowering.

NOTE: The Turbine may revert to OPER AUTO due to the pressure bias before the crew can take the action to place in a manual mode (OPER AUTO or MANUAL)

CRS Direct the CBOT to place the turbine EHC control in Operator Auto or Turbine Manual mode.

CBOT Place the turbine EHC in either Operator Auto or Turbine Manual mode.

CBOR Acknowledge and report ICS in Track annunciator alarm.

NOTE: The CRS may also direct the placement of the SG/RX Master station to HAND, but is not mandatory.

CRS Direct the CBOT to slowly lower the turbine demand signal in manual to recover (lower) turbine header pressure.

CBOT Using the EHC control buttons for Operator Auto or Turbine Manual mode, lower the demand signal and observe the turbine load is lowering and turbine header pressure in beginning to rise back toward setpoint.

Event Termination:

When the plant is stable OR Next event Page 9 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 6 Event

Description:

Loss of non vital bus B3 Time Position Applicants Actions or Behavior T=57 CBOT Identify the loss of bus B3 based on loss of lighting, annunciator alarms associated with electrical distribution and AMP meters on C10.

CRS Direct plant operations as per 1203.046, Loss of Load Center, section 3.3.

CBOT/ Verify Condenser Vacuum Pump C-5B running.

CBOR CBOT Verify Turbine Generator EHC oil pump P-14B running.

CRS Dispatch the Auxiliary Operator to verify Isophase Bus Cooler Fan, C-8B running.

CRS Dispatch the Auxiliary Operator to verify C-28B running.

CRS Dispatch an Auxiliary Operator to align the B Main Phase Transformer per instruction in 1203.046, step 3.4.5.

CBOT Verify Gland Steam Cond. Exhauster (C-1B) running.

CBOT/ Verify Backup Air Side Seal Oil Pump P-25 running.

CBOR CRS Refer to list on page 7 of 1203.046 and Attachment D of Electrical System Operations (1107.001) to determine any additional components that may require actions.

Event Termination:

When the plant is stable and investigation of the Loss of B3 is directed OR Next event Page 10 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 7, 8, 9 Event

Description:

Random electrical grid upsets result in loss of offsite power. Reactor trip.

Degraded Power. EDG #2 service water valve (CV3807) breaker trips during opening causing minimal flow to the EDG for cooling. All MSLI pushbuttons on the EFIC Remote Switch Matrix fail to manually actuate the MSLI function requiring alternative effort for performing function.

Time Position Applicants Actions or Behavior T=67 CREW Recognize and report the reactor trip and loss of offsite power CRS Direct immediate actions per the Reactor Trip Procedure, 1202.001.

CBOR Manually trip the reactor by depressing the Rx. Trip pushbutton. Verify all rods on bottom and power dropping. Report to the CRS when asked.

CBOT Manually trip the turbine by depressing the Turbine Trip pushbutton. Report to the CRS when asked.

CBOR/ Verify adequate subcooling margin. Report to the CRS when asked.

CBOT CRS Transition to the Degraded Power Emergency Operating Procedure (1202.007).

Direct operations per 1202.007.

(Tech Spec. 3.8.1.C, AC Sources - Operating, Two required offsite circuits inoperable)

CBOT Verify both EDGs supplying associated ES buses with proper voltage, frequency and loading:

4100 to 4200V

59.5 to 60.5 Hz

2750 kw CBOT/ Verify SW to DG1 and DG2 CLRs open to operating EDGs (CV-3806 and CBOR 3807).

CT CBOT Report to the CRS that the service water valve to the #2 EDG, CV3807, is de-energized and cannot verify the position.

CRS Dispatch the Auxiliary Operator to the #2 EDG room to investigate the status of the service water valve, CV3807, and position. Instruct him to manually open the valve if it is not open.

-Continued-Page 11 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 7, 8, 9 Event

Description:

Random electrical grid upsets result in loss of offsite power. Reactor trip.

Degraded Power. EDG #2 service water valve (CV3807) breaker trips during opening causing minimal flow to the EDG for cooling. All MSLI pushbuttons on the EFIC Remote Switch Matrix fail to manually actuate the MSLI function requiring alternative effort for performing function.

Time Position Applicants Actions or Behavior CRS Discuss the contingency plan with the CBOT to secure the #2 EDG if service water is not aligned and a Critical Trouble annunciator alarm is received.

NOTE: Call as the Auxiliary Operator and inform the CRS that the service water valve may be partially open but the valve will not manually open any further. It appears to be mechanically failed.

CBOT Verify OR start a Service Water pump on each operating DG, after 15-second time delay (P4A, B, C).

CBOR Actuate MSLI for both SGs AND verify proper actuation and control of EFW and MSLI (RT 6): Identify that the remote switch matrix will not work to actuate MSLI for either OTSG on either train.

(Tech. Spec. 3.3.12 Emergency Feedwater Initiation and Control (EFIC)

Manual Initiation)

Two manual initiation switches per actuation train for each of the following EFIC Functions shall be OPERABLE:

a. Steam generator (SG) A Main Steam Line Isolation;

b. SG B Main Steam Line Isolation; and

c. Emergency Feedwater (EFW) Initiation.)

CRS Direct the CBOR to manually close the MSIVs and MFIVs on panel C09 or use the trip modules in the EFIC cabinets to actuate MSLI for both OTSGs.

CBOR Close the MSIVs and MFIVs for both OTSGs using the handswitches on C09 OR go to the EFIC cabinets and actuate MSLI for both OTSGs on both trains on the trip modules. Verify the actions per RT6 steps C. and D.

CRS Check RCS press remains 1700 psig AND PZR level remains 30".

CBOT Isolate Letdown by closing either:

Letdown Coolers Outlet (CV-1221)

OR Letdown Cooler Outlets (CV-1214 and 1216).

-Continued-Page 12 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 1 Event No: 7, 8, 9 Event

Description:

Random electrical grid upsets result in loss of offsite power. Reactor trip.

Degraded Power. EDG #2 service water valve (CV3807) breaker trips during opening causing minimal flow to the EDG for cooling. All MSLI pushbuttons on the EFIC Remote Switch Matrix fail to manually actuate the MSLI function requiring alternative effort for performing function.

Time Position Applicants Actions or Behavior CBOT Place RCP Seal Bleedoff (Alternate Path to Quench Tank) controls in CLOSE (SV-1270, 1271, 1272 and 1273).

CT CBOT Isolate RCP Seal Bleedoff (Normal) by closing either:

CV-1274 on C16 OR CV-1270, 1271, 1272, and 1273 on C18.

CRS When the #2 EDG Critical Trouble annunciator is received, direct the CBOT to secure the #2 EDG.

CBOT On panel C10, place the control switch for #2 EDG in the LOCKOUT position and verify the EDG stops.

(Tech. Spec. 3.8.1.B, Two diesel generators (DGs) each capable of supplying one train of the onsite Class 1E AC Electrical Power Distribution System.)

CRS Return to Step 1 of Degraded Power procedure and perform the contingency steps for one EDG available.

CRS Call Unit 2 control room and request the use of the Alternate AC Generator.

CRS When Unit 2 informs him the Alternate AC Generator is ready for use, Direct the CBOT to energize the A4 Bus from the AAC Generator.

CBOT Using the guidance in 1107.002, step 31.2, energize the A4 Bus from the AAC Generator.

SCENARIO TERMINATION When the actions are complete to the point of awaiting the return of offsite power OR At the direction of the Lead Evaluator, terminate the scenario Page 13 of 13

Appendix D Scenario 2 Form ES-D-1 Facility: ANO-1 Scenario No.: 2 Op-Test No.:2005-1 NEW Examiners: Operators:

Initial Conditions: IC 102 100% power; Equilibrium xenon Power has been stable at 100% for last two days following return to full power after maintenance to the B main feedwater pump.

Chemistry is performing routine Tech Spec chemistry and sampling is aligned from pressurizer water space per 1104.002, Section 19.2.

Turnover:

100% power; Equilibrium xenon Power has been stable at 100% for last two days following return to full power after maintenance to the B main feedwater pump.

Chemistry is performing routine Tech Spec chemistry and sampling is aligned from pressurizer water space per 1104.002, Section 19.2.

CV1207 seal injection control valve is in hand.

Small fuel leak based on RCS isotopic analysis for Cycle 19.

Event Malf. No. Event Event No. Type* Description 1 N/A N (CBOR) Chemistry calls and reports boron samples with a 55 PPM difference. Equalize RCS/Pzr boron concentration 2 CV1008 .12 C (CBOR) Pressurizer Spray Valve fails open 3 FW087 C (CBOT) Heater drain pump B bearing heat up resulting in need to trip the pump. Pump will trip if no action is taken. (2 min.15 sec.- alarm, 3 min. 15 sec. -trip) 4 N/A R (CBOR) Lower power to ~70% in response to a trip of a heater drain pump 5 DI_ICC0009L C (CBOR) ULD station fails to lower demand signal in manual False 6 TR049 0 I (CBOR) Pressurizer level transmitter fails low 7 RC001 M (ALL) OTSG tube leak progressing to a ~150 gpm.

(.325) R20:00 R 8 DI_H15C C (CBOT) H1 feeder breaker from SU#1 transformer fails to False close when transferring auxiliaries.

9 CO_P75 C (CBOT) P75 will not start

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 13

Appendix D Scenario 2 Form ES-D-1 Scenario #2 Objectives

1) Evaluate individual response to a feedwater and condensate system component failure.

2) Evaluate individual response to an Integrated Control System failure.

3) Evaluate individual response to a transmitter signal input failure to a controlling function.

4) Evaluate individual response to an electrical breaker failure

5) Evaluate individual response to an OTSG tube leak/rupture.

6) Evaluate individual ability to lower plant load in accordance with plant procedures.

7) Evaluate individual ability to operate controls to equalize boron concentrations between Reactor Coolant System and Pressurizer.

8) Evaluate the individual response to a failure of the RCS pressure or inventory control system component SCENARIO #2 NARRATIVE The scenario begins with an expected call from Chemistry to report the results of routine RCS sampling. The report informs the crew that a difference of 55 PPM exists between the RCS and the Pressurizer, requiring equalization to be performed to get the concentrations within 50 PPM. The crew will perform an RCS/Pressurizer boron equalization.

Using a compressed time line, Chemistry will call an inform the crew that the difference between RCS and Pressurizer boron is 5 PPM and the equalization can be secured, as they desire. The crew will take the actions to complete the equalization. As the Pressurizer spray valve is attempted to be closed, the operator will report the valve will not close and RCS pressure is continuing to decline. The crew should take the actions for a Pressurizer spray valve failure using AOP 1203.015 for guidance.

The B Heater Drain pump bearing will begin to heatup and cause an annunciator alarm.

The crew will respond to the alarm by checking for the affected pump and taking actions to stop the pump. The pump may trip before the crew can stop it, and the CRS should direct a plant power reduction to stay within the high level dump capacity of the affected heater drain tank. As the crew is performing a power reduction, the operator will report the ULD station, being used to perform the power reduction, will not respond to his command. The CRS should direct the operator to use the SG/RX Master station to perform the power reduction.

The selected pressurizer level transmitter will fail low. The crew will take action to select the redundant transmitter for indication and control .

Page 2 of 13

Appendix D Scenario 2 Form ES-D-1 SCENARIO #2 NARRATIVE (continued)

The power maneuver will cause a tube in the A OTSG to begin leaking and progress to a rupture of ~150 gpm. The crew will respond to the A N16 Alarm and begin taking the actions of AOP 1203.023, Small Steam Generator Tube Leaks. The leak will exceed 10 gpm and require the crew to transition to the OTSG Tube Rupture EOP. The crew will begin a controlled plant shutdown.

At ~50% power, when plant auxiliaries are being shifted to startup transformer, the operator will report the feeder breaker from SU#1 to the H1 bus will not close. The crew must make a decision to either place the H1 bus on SU#2 or remove the handswitch from SU#2 out of Pull-To-Lock and allow the bus to transfer to SU#2 automatically when the unit is tripped.

The crew will continue with the shutdown and at ~12% power trip the unit. The crw should begin a plant shutdown at < 100ºF/Hr. When directed to place the Auxiliary Feedwater Pump in service the pump will fail to start. This will require the crew to initiate EFW and continue the cooldown using EFW as the feedwater source until the Auxiliary Feedwater Pump is made available.

The scenario will be terminated when a cooldown is in progress and EFW is in service.

Page 3 of 13

Appendix D Scenario 2 Form ES-D-1 Simulator Instructions for Scenario 2 Event Time Malf. No. Value/ Ramp Event No. Time Description 1 T=0 N/A N/A Chemistry calls and reports boron samples with a 55 PPM difference.

Equalize RCS/Pzr boron concentration 2 T=15 IMF CV1008 .12 Pressurizer Spray Valve fails open 3 T=20 IMF FW087 N/A Heater drain pump B bearing heat up resulting in need to trip the pump. Pump will trip if no action is taken. (2 min.15 sec.- alarm, 3 min. 15 sec. -trip) 4 N/A N/A N/A Lower power to ~70% in response to a trip of a heater drain pump 5 N/A IOR False ULD station fails to lower demand signal DI_ICC0009L in manual 6 T=35 IMF TR049 0 Pressurizer level transmitter fails low 7 T=40 IMF RC001 .325 OTSG tube leak progressing to a ~150 R20:00 gpm.

8 Pre- IOR False H1 feeder breaker from SU#1 transformer loaded DI_H15C fails to close when transferring auxiliaries.

9 Pre- IRF CO_P75 P75 will not start loaded Page 4 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 1 Event

Description:

Chemistry calls and reports boron samples with a 55 PPM difference. Equalize RCS/Pzr boron concentration Time Position Applicants Actions or Behavior ROLE PLAY: Call as Chemistry and report RCS boron concentration is 782 PPM and Pressurize boron concentration is 837 PPM.

T=0 CRS Determine the need to equilize boron between the Pressurizer and RCS based on the report from Nuclear Chemistry that the Pressurizer is >50 ppm higher than the RCS.

CRS Using normal operations procedure 1103.005, direct the equilization of boron by either method 1 or 2.

CBOR IF using method 1:

Place Pressurizer spray valve in manual and open slightly

Place some Pzr heaters in manual and throttle spray flow to hold pressure steady

Monitor RCS pressure closely.

CBOR IF using method 2:

Place desired Pzr heaters in manual and monitor RCS pressure closely.

Verify Pzr spray valve cycles automatically to control RCS pressure between 2205 and 2155 psig CRS Announce if any upset occurs while equalizing boron, immediately return Pressurizer heaters to automatic NOTE This evolution should continue until another events occurs Page 5 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 2 Event

Description:

Pressurizer Spray Valve fails partially open.

Time Position Applicants Actions or Behavior ROLE PLAY: Using time compression to complete the evolution, call as Chemistry and report the difference between RCS and Pressurizer boron is <5 PPM and equalization can be secured.

T=15 CRS Direct the CBOR to place the pressurizer heaters and spray valve in AUTO.

CBOR Placed all pressurizer heaters and the pressurizer spray valve in AUTO.

CBOR Report the pressurizer spray valve shows intermediate position and RCS pressure continues to lower.

CRS Direct operations per 1203.015, Section 6, Pressurizer System Failure AOP, for a failed Pressurizer Spray Valve.

T.S. TRM 3.4.3 Pressurization, Heatup and Cooldown Limitations CBOR Place the spray valve, CV1008, in MANUAL and hold in the close position.

Report the valve did not close.

CRS Direct the CBOR to isolate the spray valve by closing the Pressurizer Spray Valve Isolation, CV1009.

CBOR Closed CV1009 on C04 CBOR Verify pressurizer heaters are energized and begin to restore RCS pressure.

EVENT TERMINATION CRITERIA Pressurizer spray valve is isolated and RCS pressure is recovering Page 6 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 3, 4, 5 Event

Description:

Heater drain pump B bearing heat up resulting in need to trip the pump. Pump will trip if no action is taken. Lower power to ~70% in response to a trip of a heater drain pump. ULD station fails to lower demand signal in manual.

Time Position Applicants Actions or Behavior T=20 CBOR Acknowledge and report Heater Drain Pump Bearing Temp Hi alarm, K06-E8.

CRS Direct actions per 1203.012E , Annunciator Corrective Action for K06-E8.

CBOT Check TR-2890 for the affected pump. Determine and report P8B bearing temperature rising.

NOTE: The crew may elect to stop the heater drain pump prior to it tripping due to the fault.

CBOR/ Report P8B, Heater Drain Pump, trip.

CBOT CRS Direct operations per ACA 1203.012E, K06-A8 (P8A/B Flow Lo) and/or 1203.012E, K06-B7 (Condensate Pump Autostart).

CBOR Commence reduction in unit load to ~70% at ~10%/minute using the ULD.

CBOR Report to the CRS that the ULD will not change demand as requested.

CRS Direct the CBOR to place the SG/RX Master H/A station in HAND and lower power to ~70% at ~10%/minute.

NOTE: In the manual mode on the SG/RX master, the operator has control of the rate the plant will change. It is expected the operator will maintain the rate of change near the directed rate by the CRS.

CBOR Place the SG/RX master in HAND and slowly toggled down, checking to determine the rate directed by the CRS.

-Continued-Page 7 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 3, 4, 5 Event

Description:

Heater drain pump B bearing heat up resulting in need to trip the pump. Pump will trip if no action is taken. Lower power to ~70% in response to a trip of a heater drain pump. ULD station fails to lower demand signal in manual.

Time Position Applicants Actions or Behavior CBOT Verify Turbine EHC responds to lowering load and maintains header pressure at or near setpoint. (Auto or manual)

CBOR Stabilize plant when power approaches ~70%.

EVENT TERMINATION CRITERIA Plant is stabilized at or near 70% power Page 8 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 6 Event

Description:

Pressurizer level transmitter fails low Time Position Applicants Actions or Behavior T=35 CBOR Acknowledge and report Pressurizer Level Lo and Pressurizer Level Lo-Lo alarms.

CRS Refer to Annunciator Corrective Action for K09-A3 and K09-C3.

CBOR Determine and report cause of Low level alarm is due to instrument failure.

CRS Refer to Pressurizer Systems Failure Abnormal Operating Procedure, 1203.015.

(Tech Spec. 3.3.15.A, Post Accident Monitoring (PAM) Instrumentation.)

CBOT Check redundant level transmitter on PMS for validity.

CRS If desired direct the CBOR to place the Pressurizer Level control valve, CV1235, in HAND and adjust as necessary to stabilize Pressurizer level.

CBOR If directed, place CV1235 in HAND and close valve and allow the level do drop to desired level.

CRS Direct the redundant level transmitter selection on C04.

CBOR On C04, place HS-1002 to LT1002 (good transmitter). Verify the level indication responds to selected transmitter.

CRS Direct the CBOR to place CV1235 in AUTO if placed in MANUAL earlier.

CBOR Place CV1235 in AUTO and verify proper control.

EVENT TERMINATION CRITERIA Pressurizer level selected to the good transmitter OR next event.

Page 9 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 7, 8, 9 Event

Description:

OTSG tube leak progressing to a ~150 gpm. H1 feeder breaker from SU#1 transformer fails to close when transferring auxiliaries. P75 will not start.

Time Position Applicants Actions or Behavior T=40 CBOR/T Identify and report A OTSG N16 TROUBLE annunciator (K07-A5).

CBOR Begin leak rate determination.

Tech. Spec. 3.4.13 RCS Operational LEAKAGE EAL 3.2 NUE OTSG Tube Leak > T.S. Limit CRS Reference Small Generator Tube Leaks Abnormal Operating procedure (1203.023).

ROLE PLAY If notified as Chemistry to determine leak rate; using steam generator sample wait ~8 minutes (Time Compressed) then report approximate leak rate displayed on PS1 display.

CRS Reference Rapid Plant Shutdown Abnormal Operating procedure (1203.045).

Direct CBOT/CBOR to commence a plant shutdown at ~5% per minute.

CBOR/ Begin plant shutdown using the SG/RX Master H/A station in MANUAL.

CBOT CBOR/ Report the leak rate has exceeded 10 GPM.

CBOT CRS Transition to OTSG Tube Rupture Emergency Operating procedure (1202.006).

CRS Direct the CBOT to OPEN the BWST Outlet to the operating makeup pump.

CBOT Open the BWST Outlet valve to the operating makeup pump.

CRS Direct Auxiliary Operators to implement Control of Secondary Contamination Abnormal Operating procedure (1203.014).

CBOR Place SG EFW Pump Turbine (K3) Steam Supply valve (CV-2667) in MANUAL and close.

-Continued-Page 10 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 7, 8, 9 Event

Description:

OTSG tube leak progressing to a ~150 gpm. H1 feeder breaker from SU#1 transformer fails to close when transferring auxiliaries. P75 will not start.

Time Position Applicants Actions or Behavior CT CBOT Initiate HPI per RT2 as required. (If < 200 inches, perform RT2)

CBOT When unit is <70% stop Heater Drain Pumps (P8A, B).

CBOT When unit is <50% transfer station auxiliaries to Start Up #1 transformer.

CBOT Report that the breaker H15, SU#1 transformer to H1 bus, will not close.

NOTE: The CRS may elect to place H1 bus on SU#2 transformer or remove the handswitch for SU#2 from P-T-L and allow the bus to transfer to SU#2 when the unit is tripped.

CRS When <350 MW and the Main Block Valves are closed, direct the CBOR to OPEN the FW cross-tie valve and trip the B MFW pump.

CBOR Open the FW cross-tie valve and trip the B MFW pump.

CBOR When both SGs are on low level limits;

1. Place both Feedwater Demand H/A Stations in HAND

2. Adjust demands to zero

3. Place Reactor Demand H/A station in HAND

4. Adjust to control reactor power at 10-12%.

CBOT When unit is <180 MW open HP Turbine Drain valves on C02.

CBOT When unit is <100 MW secure reheaters.

CBOR When reactor power is <12%

1. Select bad SG to indicate on Header press recorder.

2. Check Turbine Bypass valves controlling header pressure 880-920 psig

3. Verify plant auxiliaries on SU1 CRS Check PZR Level >200.

-Continued-Page 11 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 7, 8, 9 Event

Description:

OTSG tube leak progressing to a ~150 gpm. H1 feeder breaker from SU#1 transformer fails to close when transferring auxiliaries. P75 will not start.

Time Position Applicants Actions or Behavior CBOR Trip Reactor AND immediately adjust Header Pressure Controller setpoint to 45.

Verify all rods inserted AND Reactor power dropping.

CBOT Verify Turbine tripped.

CBOR Check Turbine Bypass valves controlling OTSG pressure 950-990psig.

CBOR Operate PZR heater and spray in hand as required to maintain RCS pressure low within the limits of figure 3.

CBOR/ Stabilize PZR level >55.

CBOT CBOT Verify OTSG N16 monitors selected to GROSS position.

CRS Direct the CBOR to begin a cooldown at < 100º F/Hr.

CT CBOR Place Turbine Bypass valves for the B OTSG in hand and adjust to initiate and maintain a cooldown rate of <100°F/Hr.

CRS Direct placing the Auxiliary Feed pump, P75, in service.

CBOT Attempt to start P75 from the handswitch on C12. Report to the CRS that P75 will not start.

CRS Go To step 24 and direct the CBOR to actuate EFW and verify proper actuation and control (RT 5).

CBOR Actuate EFW and verify proper actuation and control (RT 5).

-Continued-Page 12 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 2 Event No: 7, 8, 9 Event

Description:

OTSG tube leak progressing to a ~150 gpm. H1 feeder breaker from SU#1 transformer fails to close when transferring auxiliaries. P75 will not start.

Time Position Applicants Actions or Behavior CBOR Trip the A MFW pump.

CRS Transition to step 47.

SCENARIO TERMINATION CRITERIA RCS cooldown in progress and EFW in service OR As directed by the lead examiner.

Page 13 of 13

Appendix D Scenario 3 Form ES-D-1 Facility: ANO-1 Scenario No.: 3 Op-Test No.:2005-1 NEW Examiners: Operators:

Initial Conditions: IC 103 ICS in Automatic at ~25% power following a mid-cycle shutdown.

Power escalation is in progress per the Startup and Power Operations procedures.

A MFW pump is in service and B MFW pump is running at minimum speed.

Turnover:

ICS in Automatic at ~25% power following a mid-cycle shutdown.

Power escalation is in progress per the Startup and Power Operations procedures.

A MFW pump is in service and B MFW pump is running at minimum speed.

CV1207 seal injection control valve is in hand.

Event Malf. No. Event Event No. Type* Description 1 N/A R (CBOR) Power escalation from ~25% power to 35% power to place B MFP in service 2 AI_TIC4018S C (CBOT) Automatic control of CV4018 fails to maintain

(.7) generator temperatures 3 N/A N (CBOR) Place the second main feedwater pump in service 4 TR575 0 R20 I (CBOR) B OTSG startup level transmitter fails low 5 CW084 C (CBOT) P3C, Circulating Water Pump, winding temperature begins to heatup due to internal motor problem.

6 RC464 2.5 M (ALL) LOCA- Leak on an HPI line inside containment R7:00 7 RP245 C (CBOR) RPS fails to trip the reactor automatically on a valid RP246 RPS trip setpoint. The Manualtrip button on C03 fails to perform a reactor trip. (The backup RP247 pushbuttons on C03 must be depressed to RP248 complete a reactor trip)

DI_ICC0020 (False) 8 CV1407 C (CBOT) BWST outlet valve CV1407 fails to open on ESAS signal

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 12

Appendix D Scenario 3 Form ES-D-1 Scenario #3 Objectives

1) Evaluate individual response to component failures affecting cooling of the main turbine generator.

2) Evaluate individual response to input failures to the Integrated Control System.

3) Evaluate individual response to a loss of reactor coolant accident

4) Evaluate individual response to failure of automatic actuation systems.

5) Evaluate individual response to failure of Emergency Core Cooling System components.

6) Evaluate individual ability to maneuver the plant in accordance with plant procedures.

7) Evaluate individual ability to start and operate feedwater and condensate system components in accordance with plant procedures.

8) Evaluate individual response to failure of system or components associated with control of the secondary heat removal capabilities.

SCENARIO #3 NARRATIVE This scenario begins with the plant at ~25-30% power with the A Main Feedwater Pump operating, and the Integrated Control System in AUTO with the exception of the ULD (STAR Module) which is in manual to perform power escalation. When the crew accepts responsibility for the control boards, the first event will be a power escalation to ~35-40%

power to place the B Main Feedwater Pump in service and split the feedwater loops.

As plant load is increased, a failure of the automatic control valve for control of Auxiliary Cooling Water to the Main Generator hydrogen coolers causes Generator gas temperatures to begin rising. The crew will respond to alarms associated with generator gas temperature monitor and take manual control of the ACW control valve and regain cooling of the hydrogen gas.

The crew will place the B Main Feedwater Pump in service and prepare to continue the power escalation.

After the Feedwater pump is placed in service (AUTO) the selected B OTSG Startup Level transmitter will fail low requiring the crew to stop the Feedwater transient that occurs as the B Main Feedwater pump overfeeds the B OTSG. When the crew stabilizes the plant, they will select the good transmitter for control and place the ICS stations in AUTO.

The C Circulating Water Pump, P3C, will experience an internal electrical failure that will cause the winding temperature to rise to alarm setpoint. The crew will respond to the alarms and take actions to secure the faulted pump or respond to the trip of the pump.

The idle pump should be placed in service. The crew should also monitor for loss of vacuum and lower plant load, if necessary, to stabilize vacuum.

Page 2 of 12

Appendix D Scenario 3 Form ES-D-1 SCENARIO #3 NARRATIVE (continued)

A reactor coolant system leak on an HPI line will cause RCS pressure to begin to rapidly drop. The crew should identify the LOCA and trip the unit. The RPS will fail to perform an automatic trip if the low pressure trip setpoint is reached and will require the crew to manually trip the reactor. The normal reactor trip pushbutton will fail to trip the reactor and the operator will need to use the backup trip pushbuttons on C03. The reactor will trip and the crew will perform the immediate actions of the Reactor Trip EOP and identify the failure of the RPS to perform its function.

RCS pressure will drop to the ESAS actuation setpoint and ESAS will actuate. CV1407, the BWST outlet to the Red Train components, will fail to open. The crew should stop the ES pumps associated with the RED train until the valve can be manually opened locally. While performing verifications of proper actuation of components, the operator will discover a difference in flows on the only operating HPI loop and throttle the valve associated with high flow to within 20 gpm of the other flows.

The scenario will be terminated when the RED train is restored to operation following the opening of CV1407 and EFW is feeding both OTSGs.

Page 3 of 12

Appendix D Scenario 3 Form ES-D-1 Simulator Instructions for Scenario 3 Event Time Malf. No. Value/ Ramp Event No. Time Description 1 T=0 N/A N/A Power escalation from ~25% power to 35% power to place B MFP in service 2 T=0 IOR .7 Automatic control of CV4018 fails to AI_TIC4018S maintain generator temperatures 3 T~15 N/A N/A Place the second main feedwater pump in service 4 T~30 IMF TR575 0 B OTSG startup level transmitter fails R20 low 5 T~45 IMF CW084 N/A P3C, Circulating Water Pump, winding temperature begins to heatup due to internal motor problem.

6 T~55 IMF RC464 2.5 LOCA- Leak on an HPI line inside R7:00 containment 7 Pre- RP245 N/A RPS fails to trip the reactor automatically Loaded on a valid RPS trip setpoint. The RP246 N/A Manualtrip button on C03 fails to RP247 N/A perform a reactor trip. (The backup RP248 N/A pushbuttons on C03 must be depressed IOR to complete a reactor trip)

DI_ICC0020 False 8 Pre- IMF CV1407 0 BWST outlet valve CV1407 fails to open Loaded on ESAS signal Page 4 of 12

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 3 Event No: 1, 2 Event

Description:

Power escalation from ~25% power to 35% power to place B MFP in service.

Automatic control of CV4018 fails to maintain generator temperatures.

Time Position Applicants Actions or Behavior T=0 CRS Direct the crew to continue power escalation to ~350 MW at 30%/Hr. to place the B MFW pump in service.

CBOR Verify the rate of change station is set at .5%/minute (30%/Hr.) and begin a power escalation using the Unit Load Demand station. Set ULD demand to

~34-35%.

CBOT Monitor main generator hydrogen and reactive loading and maintain within the limits of Attachment N.

CBOR Compare rod index with a copy of the applicable page of Attachment K, Regulating Rod Insertion Limits ~ every 15 minutes to verify limits are not exceeded.

CBOR Monitor Heat Balance power on plant computer point XPP. Compare Heat Balance power with nuclear instrumentation.

CBOT Place Moisture Separator Reheaters in service.

CBOR Acknowledge and report annunciator K04 B6 in alarm (Generator H2 Temp HI)

CRS Provide direction per 1203.012C, Annunciator Corrective Action.

CBOT Monitor recorder TR-9001 and/or PMS dynamic alarm display for rising temperatures on the main generator.

CBOT Check/Verify CV4018, Generator Hydrogen Cooler outlet control valve on C19, operating properly.

CBOT Report the hydrogen cooler outlet control valve is closed.

CRS Direct the CBOT to attempt to manually operate the valve from the controller on C19.

-Continue-Page 5 of 12

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 3 Event No: 1, 2 Event

Description:

Power escalation from ~25% power to 35% power to place B MFP in service.

Automatic control of CV4018 fails to maintain generator temperatures Time Position Applicants Actions or Behavior CBOT Place the controller for CV4018 on C19 in MANUAL and open valve.

CBOT Monitor generator gas temperatures for stabilization or downward trending.

CBOT Adjust CV4018, manually, to control generator gas temperatures at or near desired temperature.

CRS Direct the CBOT to monitor PMS points XI-9003 and AI-9002, and points on TR-9001 for signs of generator winding degradation.

CBOT Using PMS and TR-9001, checked indications of generator winding degradation.

EVENT TERMINATION CRITERIA Main generator gas temperatures under control and power escalation resumes.

Page 6 of 12

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 3 Event No: 3 Event

Description:

Place the second main feedwater pump in service Time Position Applicants Actions or Behavior T~15 CRS Direct the CBOR to place the B MFW pump in service.

CBOR Verify that the in-service MFW Pump H/A station is in auto and maintaining FW valve train P at ~70 psid.

CBOR Slowly accelerate the 2nd MFWP until the in-service MFWP starts to slow.

CRS Direct the CBOT to reset RPS trips per Plant Startup (1102.002), Attachment E, "Anticipatory Reactor Trip System (ARTS) Reset" for the 2nd MFWP.

NOTE: There is only one RPS cabinet. RESET of ARTS in this cabinet will reset the function in all channels.

CBOT Reset RPS trips for the 2nd MFWP.

CBOR Verify Main Feed Pump Recirc Control Valves closed AND controllers in AUTO.

CBOR Continue accelerating the 2nd MFWP until the following available parameters for both MFWPs are approximately equal:

Speed

Discharge pressure, if available

Suction flows on Feed Pumps Recirc H/A stations CBOR Close Feedwater Pumps Discharge Crosstie (CV-2827).

CBOR Verify each MFWP either maintaining respective valve train P at ~70 psid.

CBOR Place the 2nd MFW Pump H/A station into AUTO.

EVENT TERMINATION CRITERIA B MFW Pump is in AUTO Page 7 of 12

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 3 Event No: 4 Event

Description:

B OTSG startup level transmitter fails low Time Position Applicants Actions or Behavior T~30 CBOR Acknowledge and report SASS Mismatch annunciator alarm, K07-B4.

CBOR Acknowledge and report B OTSG Low Level Limit alarm, K07-F3.

CRS Direct operation in accordance with ACA 1203.012F.

CBOR Recognize and report the B MFW pump speed rising and feedwater flow rising in the B feedwater loop.

CRS Direct the CBOR to place the B MFW pump H/A station in HAND and stop the rise in feedwater flow.

CBOR Place the B MFW pump H/A station in HAND and use the toggle switch to lower feedwater flow slightly to gain control of feedwater flow.

CRS Direct the CBOT to check the redundant instrument for a valid signal using PMS.

CBOT Check PMS and determine the opposite instrument in the B loop is indicating a valid signal.

CRS Direct the CBOR to select the NNI Y Startup level transmitter in the B loop.

CBOR Select the NNI Y Startup level instrument in the B loop and verify correct response.

CRS Direct the CBOR to place the B MFW pump H/A station in AUTO.

CBOR Using 1105.004, ICS Operations procedure, place the B MFW pump H/A station in AUTO.

EVENT TERMINATION CRITERIA B Startup Level Transmitter Y instrument selected and B MFW pump H/A station in AUTO Page 8 of 12

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 3 Event No: 5 Event

Description:

P3C, Circulating Water Pump, winding temperature begins to heatup due to internal motor problem.

Time Position Applicants Actions or Behavior T~45 CBOR Acknowledge and report K05-D1, Circ Water Pump Motor Winding Temp. HI, in alarm.

CRS Direct operations as per Annunciator Corrective Action 1203.012D, K05-D1.

CBOT Determine which point is in alarm on recorder TR2808 on C19 or PMS displays for the circ water pumps.

CRS Dispatch the Auxiliary Operator to investigate the circ water pump for cause of alarm.

NOTE: The C Circ Water Pump may trip before the CRS can direct the pump be stopped.

CRS Direct the CBOT to stop P3C, Circ Water Pump.

CBOT On C13, stop P3C. Observe the Discharge valve closes.

CRS IF P3C trips prior to being stopped, direct the CBOT to start the idle circulating water pump.

CBOT Start the idle circulating water pump and verify the discharge valve opens.

CRS If necessary, direct the CBOR to reduce power to stabilize vacuum.

CBOR IF directed, use the ULD station to reduce power to stabilize vacuum.

EVENT TERMINATION CRITERIA Next Event Page 9 of 12

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 3 Event No: 6, 7, 8 Event

Description:

LOCA- Leak on an HPI line inside containment. RPS fails to trip the reactor automatically on a valid RPS trip setpoint. The Manual trip button on C03 fails to perform a reactor trip. (The backup pushbuttons on C03 must be depressed to complete a reactor trip). BWST outlet valve CV1407 fails to open on ESAS signal Time Position Applicants Actions or Behavior T~55 CBOR Identify pressurizer level and RCS pressure dropping.

CBOT Recognize and report RCS leakage into the Reactor Building.

Tech Spec. 3.4.13.B RCS Operational LEAKAGE EAL 2.2, ALERT(RCS leakage >Normal Makeup capacity)

NOTE: The crew may manually trip the reactor prior to reaching the low RCS pressure setpoint and therefore not see the RPS failure to perform an automatic trip.

CRS Direct the CBOR/CBOT to trip the reactor and carry out the immediate actions.

(This direction may or may not occur prior to an automatic trip)

CBOR Depress the Reactor Trip push-button on C03.

Verify the reactor trips and power is dropping.

CBOR Diagnose Rx trip pushbutton failure Tech. Spec. 3.3.1 Reactor Protection System (RPS) Instrumentation Tech. Spec. 3.3.2 Reactor Protection System (RPS) Manual Reactor Trip EAL 6.2 (Alert) Reactor Protection System Failure to Complete an Automatic Trip CT CBOR Depress both shunt trip pushbuttons on C04 CBOT Depress the Turbine Trip pushbutton on C01. Verify Turbine throttle and governor valves closed.

CRS Direct initiation of HPI per RT 2.

CREW Recognize the actuation of ESAS on low RCS pressure.

CRS Transition to ESAS procedure, 1202.010, and direct crew operations

-Continued-Page 10 of 12

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 3 Event No: 6, 7, 8 Event

Description:

LOCA- Leak on an HPI line inside containment. RPS fails to trip the reactor automatically on a valid RPS trip setpoint. The Manual trip button on C03 fails to perform a reactor trip. (The backup pushbuttons on C03 must be depressed to complete a reactor trip). BWST outlet valve CV1407 fails to open on ESAS signal Time Position Applicants Actions or Behavior CBOT Recognize the BWST outlet, CV1407, didnt open and report to the CRS.

Secure P36A, HPI pump, and P34A, LPI pump, after selecting MAN.

CBOR Check for adequate subcooling margin. (>30ºF)

CRS Direct the Waste Control Operator to manually open CV1407.

IA OPERATOR NOTE: When the WCO is sent to manually open CV1407, open the valve.

IMF CV1407 1 240 CBOT Verify proper ESAS actuation per RT 10.

CBOR Close or verify closed the following valves; CV-1008, CV-1009, and CV-1000 CT CBOT Recognize only one train of HPI in service and HPI flow through one nozzle is excessive. Throttled CV1284 to within 20 gpm of the next highest flow.

CBOR Control RCS pressure within limits of Figure 3 of EOP (RT 14)

NOTE: IF subcooling margin is less than adequate (<30ºF), transition to the Loss of Subcooling Margin procedure and perform the following steps.

CBOR/ Report subcooling margin is inadequate.

CBOT CRS Transition to Loss of subcooling margin procedure, 1202.002, and direct crew actions.

-Continued-Page 11 of 12

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 3 Event No: 6, 7, 8 Event

Description:

LOCA- Leak on an HPI line inside containment. RPS fails to trip the reactor automatically on a valid RPS trip setpoint. The Manual trip button on C03 fails to perform a reactor trip. (The backup pushbuttons on C03 must be depressed to complete a reactor trip). BWST outlet valve CV1407 fails to open on ESAS signal Time Position Applicants Actions or Behavior CRS Direct stopping all reactor coolant pumps.

CT CBOT Stop all reactor coolant pumps within 2 minutes OR trip one RCP per loop.

CBOR Control RCS pressure within limits of Figure 3 of EOP (RT 14)

CRS When CV1407 is reported OPEN, direct the CBOT to start P36C, if the pump did not trip earlier.

CBOT Start P36C by placing the auto/man pushbutton to MAN. Verify P36C starts and flow in HPI lines.

CRS Direct initiation of RT3, Full HPI.

CBOT Initiate full HPI using Repetitive Task 3 (RT3).

SCENARIO TERMINATION CRITERIA Full HPI in service, EFW feeding both OTSGs OR Directed by Lead Examiner Page 12 of 12

Appendix D Scenario 4 Form ES-D-1 Facility: ANO-1 Scenario No.: 4 (Spare) Op-Test No.:2005-1 NEW Examiners: Operators:

Initial Conditions: IC 104 100% Power, Equilibrium Xenon Turnover:

100% Power, Equilibrium Xenon, MOL (250 EFPD)

An RCS delithiation is anticipated for this shift. Chemistry will call to provide the duration of the evolution.

CV1207, Seal Injection control valve, is in manual due to oscillations of seal injection when in auto.

Main Steam Safety Valve PSV2687 on the B main steam line is gagged due to premature lifting.

Event Malf. No. Event Event No. Type* Description 1 BAT CRD.txt I(CBOR) CRD position indication faulty with a CRD W/D (Batch file that creates inhibit this condition) 2 N/A N (CBOR) Perform 5 minute RCS delithiation at the request of chemistry. (Idle purification DI is ~65 PPM above RCS boron concentration) 3 BAT ES19_2.txt C (CBOT) Condenser vacuum leak caused by the failure of (Batch file that creates the #5 turbine bearing gland seal regulator.

this condition) 4 N/A R (CBOR) Power reduction to stabilize vacuum 5 CV098 C (CBOT) Operating MU/HPI pump experiences high winding temperature and causes the pump to trip. The standby pump has no oil indicated in one of the oil bubblers and must have oil added prior to start.

6 MS143 M (ALL) Main steam safety valve associated with B OTSG MS134 .4 experiences structural failure and lifts. Steam Leak significant to warrant manual reactor trip.

7 TU155 C (CBOT) The main turbine fails to fully trip when the unit is TU156 tripped. One governor valve and one throttle valve fail to close, requiring the crew to shut the MSIV from the affected OTSG.

8 CV2648 C (CBOR) EFW valves to B OTSG from P7B fail open and CV2626 will not close from the handswitches.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 13

Appendix D Scenario 4 Form ES-D-1 Scenario #4 Objectives

1) Evaluate individual ability to perform an RCS delithiation in accordance with plant procedures.

2) Evaluate individual ability to perform a plant power reduction and stabilize the plant in accordance with plant procedures.

3) Evaluate individual response to faulty control rod position indication.

4) Evaluate individual response to a loss of condenser vacuum.

5) Evaluate individual response to loss of RCS makeup due to an HPI pump trip.

6) Evaluate individual response to a main steam line break/overcooling event.

7) Evaluate individual response to failure of the main turbine steam valves to close on a turbine trip.

8) Evaluate individual response to a failure of Emergency Feedwater System components.

SCENARIO #4 NARRATIVE The scenario begins with the crew responding to annunciator alarms associated with the Control Drive System. The Control Rod Asymmetric and CRD Withdrawal Inhibit alarms are received and the crew will refer to the respective Annunciator Corrective Action procedures for direction. The ACAs will direct the crew to the CRD Malfunction AOP and the crew will begin diagnosing the situation. It should be determined by the crew that the condition is caused by faulty indication for Group 2, Rod #4. The crew will perform the actions required for a faulty control rod indication problem and bypass the alarm function for that rod. This will allow the crew to reset the asymmetric condition and regain control of the movement of the rods inhibited by the asymmetric condition.

Chemistry will call the control room and request they perform the 5 minute delithiation or the RCS that was anticipated at turnover. Chemistry will inform the crew that the idle Purification Demineralizer is 65 PPM boron higher than the current RCS boron concentration. The crew will refer to the Makeup and Purification procedure, 1104.002, and perform the actions for RCS Delithiation.

Condenser vacuum will begin to slowly decline and annunciators associated with the main turbine bearing #5 gland seal will alert the crew of a problem with the gland seal supply to the #5 bearing. The crew will respond to the ACA for the #5 bearing gland seal and Loss of Condenser Vacuum AOP. The crew will reduce plant load to stabilize vacuum. Gland sealing steam will be restored to the bearing gland and the vacuum will recover.

The operating makeup pump will experience rising motor windings temperatures due to an electrical fault in the motor. The crew will be prompted by an annunciator alarm and respond to stop the affected pump and start the standby makeup pump. The pump may trip prior to stopping and the crew should refer to the AOP for Loss of Reactor Coolant Makeup, 1203.026. The standby pump will be placed in service.

Page 2 of 13

Appendix D Scenario 4 Form ES-D-1 SCENARIO #4 NARRATIVE (continued)

The crew will receive an MSSV OPEN annunciator alarm. Verification using the SPDS will identify one MSSV on the B main steam line open and the crew will dispatch an operator to confirm steam releasing from exhaust piping in the penthouse area. The operator will report not only steam from the exhaust piping but steam releasing from the sides of the penthouse structure, indicating a significant size steam leak. The crew will determine the leak sufficient enough to trip the unit and begin isolation of the affected OTSG. During the isolation process, the crew discovers Emergency Feedwater is still being supplied to the affected OTSG and must take action to stop the flow of feedwater to stop the overcooling that is occurring as a result of the continuous feed. The crew will have to stop the electric driven EFW pump, P7B, to stop the flow of EFW to the B OTSG.

This will allow the OTSG to boil dry and terminate the overcooling.

Page 3 of 13

Appendix D Scenario 4 Form ES-D-1 Simulator Instructions for Scenario 1 Event Time Malf. No. Value/ Ramp Event No. Time Description 1 T=2 CRD position indication faulty with a CRD W/D inhibit Perform 5 minute RCS delithiation at the 2 T=20 N/A N/A request of chemistry. (Idle purification DI is ~65 PPM above RCS boron concentration)

Condenser vacuum leak caused by the 3 T=35 BAT N/A failure of the #5 turbine bearing gland ES19_1.txt seal regulator.

4 Power reduction to stabilize vacuum N/A N/A N/A Operating MU/HPI pump experiences 5 T=45 IMF CV098 N/A high winding temperature and causes the pump to trip. The standby pump has no oil indicated in one of the oil bubblers and must have oil added prior to start.

Main steam safety valve associated with 6 T=60 IMF MS143 6 B OTSG experiences structural failure IMF MS134 .4 and lifts. Steam Leak significant to warrant manual reactor trip.

The main turbine fails to fully trip when 7 N/A IMF TU155 100% the unit is tripped. One governor valve IMF TU156 100% and one throttle valve fail to close, requiring the crew to shut the MSIV from the affected OTSG.

Pre- IMF CV2648 1 EFW valves to B OTSG from P7B fail loaded open and will not close from the 8 IMF CV2626 1 handswitches.

Page 4 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 1 Event

Description:

CRD position indication faulty with a CRD W/D inhibit Time Position Applicants Actions or Behavior T=2 CBOR Acknowledge and report annunciator alarms K08-A2 (CRD WITHDRAWAL INHIBITED) and K08-C2 (CONTROL ROD ASYMMETRIC).

CRS Direct the crew as per Annunciator Corrective Action 1203.012G, pages 7 and 14.

CRS Transition to Abnormal Operating Procedure, 1203.003 (Control Rod Drive Malfunction Action) and direct the crew actions.

CRS Direct the crew to determine if a dropped rod or if the control rod has faulty indication.

CBOR Determine that the control rod only has faulty indication due to the 100% out limit light on the PI panel on C13 still being lit.

CRS Direct an operator to bypass the alarm using the S-2 switch in the CRD cabinet.

IA NOTE: When sent to bypass the alarm with the S-2 switch, delete the asymmetric rod annunciator from alarm by deleting the override.

IRF K08C2 Normal CRS Direct the CBOR to RESET the Asymmetric Fault using 1203.012G, K08-A2, instructions.

NOTE: If the neutron error is more negative than -1%, actions per Method 1 or 2 of 1203.012G for K08-A2 must be performed to ensure a plant transient does not occur.

CBOR Verify Neutron Error on C03 is between -1% and +1%. Depress the Fault Reset on the Diamond Panel.

EVENT TERMINATION ICS in AUTO and the control rod alarms clear Page 5 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 2 Event

Description:

Perform 5 minute RCS delithiation at the request of chemistry. (Idle purification DI is ~65 PPM above RCS boron concentration)

Time Position Applicants Actions or Behavior Role Play: Call as Chemistry and request a five minute delitiation. The idle Demineralizer is ~65 PPM higher than current RCS boron concentration.

T~20 CRS Direct the CBOR to conduct a 5 minute delithiation of the RCS in accordance with 1104.002, Makeup & Purification System Operation, section 10.6.

CBOR Open inlet to delithiating DI:

T-36A Purif Demineralizer Inlet (CV-1244) or

T-36B Purif Demineralizer Inlet (CV-1245)

Close inlet to previously in-service DI (CV-1244 or CV-1245).

Check that letdown flow is approximately equal to previous value.

CBOR When no more than 2.5 minutes have elapsed, swap back to the previously in-service DI as follows:

a. Open inlet to previously in-service DI (CV-1244 or CV-1245).

b. Close inlet to delithiating DI (CV-1244 or CV-1245).

Check that letdown flow is approximately equal to previous value.

CBOR Allow plant to stabilize and then repeat placing the delithiating DI in service to achieve total delithiation time.

CRS Record the completion of the delithiation or call chemistry and inform them the evolution is complete.

EVENT TERMINATION Delithiation is complete OR next event Page 6 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 3, 4 Event

Description:

Condenser vacuum leak caused by the failure of the #5 turbine bearing gland seal regulator. Power reduction to stabilize vacuum Time Position Applicants Actions or Behavior T~35 CBOR Acknowledge and report annunciator K05-D4, GS Pressure #5 Bearing Low.

CRS Direct actions of the crew per 1203.012D for K05-D4.

CBOT Recognize and report lowering condenser vacuum.

CRS Direct operations per AOP 1203.016, Loss of Condenser Vacuum, and AOP 1203.045, Rapid Plant Shutdown.

CBOR Commence a power reduction using the ULD as directed to stabilize condenser vacuum.

CRS Direct the Auxiliary Operator to respond to bearing #5 and investigate cause of low seal pressure and restore pressure to 1-2 psig. Instruct him to bypass the regulator if necessary.

CBOT Set the Transient Low Vacuum Alarm on PMS CBOT Verify all waterbox inlet valves open and all available circulating water pumps running.

CRS Direct the Auxiliary Operator to verify proper operation of the condenser vacuum pump.

CBOT Verify Gland Seal Steam Header pressure >75 psig.

IA NOTE: After ~3 minutes from the time the AO was directed to investigate #5 bearing seal pressure, restore gland seal steam to #5 bearing.

IRF GS6826_1 1 DMF MC088 CBOT Report condenser vacuum recovering.

-Continued-Page 7 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 3, 4 Event

Description:

Condenser vacuum leak caused by the failure of the #5 turbine bearing gland seal regulator. Power reduction to stabilize vacuum Time Position Applicants Actions or Behavior CRS Direct the CBOR to stop the power reduction.

CBOR Stop the power reduction by using the ULD and matching the position and measured variable using the toggle switch.

EVENT TERMINATION Condenser vacuum recovering and power reduction stopped OR Next Event Page 8 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 5 Event

Description:

Operating MU/HPI pump experiences high winding temperature and causes the pump to trip. The standby pump has no oil indicated in one of the oil bubblers and must have oil added prior to start.

Time Position Applicants Actions or Behavior T~45 CBOR Acknowledge and report annunciator alarm K10-E7, HPI PUMP MTR WDG TEMP HI.

CRS Direct the crew per Annunciator Corrective Action,1203.012I for K10-E7.

CBOT Determine which pump is in alarm by checking Reactor Coolant, Makeup and Decay Heat Pumps Motor Winding Temperatures recorder (TR-6501) on C13.

NOTE: The operating makeup pump may trip before the crew can take the actions to start the standby pump.

CRS Direct the CBOT to start the standby makeup pump and then stop the running pump.

CBOT Start P64B, Aux L.O. pump for the standby M/U pump.

CBOT Start P36B, Standby M/U pump. Stop P64B.

CBOT Start the Aux. L.O. pump for the pump to be stopped.

CBOT Stop the M/U pump with the high temperature.

NOTE: If the running M/U pump trips before the crew stops it, the following actions should be performed:

CBOR Acknowledge and report annunciator K10-A6, HPI PUMP TRIP.

CRS Direct the crew per Abnormal Operating Procedure 1203.026, Loss of Reactor Coolant Makeup.

Tech Specs. 3.5.2.A ECCS - Operating

-Continued-Page 9 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 5 Event

Description:

Operating MU/HPI pump experiences high winding temperature and causes the pump to trip. The standby pump has no oil indicated in one of the oil bubblers and must have oil added prior to start.

Time Position Applicants Actions or Behavior CBOT Isolate letdown by performing either of the following:

Close Letdown Coolers Outlet (CV-1221),

Close Letdown Cooler Outlets (RCS) (CV-1214 and CV-1216).

CBOR Verify RC pump seals are being cooled by ICW.

CBOR Place the following valves in HAND AND close:

RC Pumps Total INJ Flow (CV-1207)

Pressurizer Level Control (CV-1235)

CBOR Verify RCP Seal Injection Block (CV-1206) closes.

CBOT Select Safety System Diagnostic Inst display on SPDS for OP HPI pump AND evaluate suction pressure and flow stability prior to event.

CRS Contact the Waste Control Operator to perform pre-start checks on the standby makeup pump.

IA NOTE: Call as the WCO and report the standby pump needs oil added to one of the bearing bubblers prior to start. Wait ~ 3 minutes and inform the control room the pump is ready to start.

CBOT Start Aux lube oil pump for STBY HPI pump.

CT CBOT WHEN Aux lube oil pump has run for 1 minute, THEN start the standby HPI pump.

CBOT Stop Aux lube oil pump for HPI pump.

CBOR Place CV-1206 pushbutton in OVRD (OVRD light on). Open CV-1206.

-Continued-Page 10 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 5 Event

Description:

Operating MU/HPI pump experiences high winding temperature and causes the pump to trip. The standby pump has no oil indicated in one of the oil bubblers and must have oil added prior to start.

Time Position Applicants Actions or Behavior CBOR Slowly open CV-1207 as follows:

A. IF seal bleedoff temperature is >180°F, THEN establish and maintain 8 to 12 gpm RCP Seal Total Injection Flow until <180°F.

B. WHEN seal bleedoff temperature is <180°F, THEN adjust CV-1207 for 30-40 gpm C. Place CV-1207 in AUTO.

CBOR WHEN RCP Seals Total INJ Flow is above setpoint (CV-1206 FLOW light on),

THEN return CV-1206 OVRD pushbutton to normal (OVRD light off).

CBOR Slowly open CV-1235 until makeup flow indication is on-scale. Adjust CV-1235 setpoint to desired value. Place CV-1235 in AUTO.

CBOR Reestablish letdown.

EVENT TERMINATION Standby M/U pump in service and letdown, makeup, and seal injection restored.

Page 11 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 6, 7, 8 Event

Description:

Main steam safety valve associated with B OTSG experiences structural failure and lifts. Steam Leak significant to warrant manual reactor trip. The main turbine fails to fully trip when the unit is tripped. One governor valve and one throttle valve fail to close, requiring the crew to shut the MSIV from the affected OTSG. EFW valves to B OTSG from P7B fail open and will not close from the handswitches Time Position Applicants Actions or Behavior T~60 CBOR Acknowledge and report annunciator K07-C5, MSSV OPEN.

Tech Spec 3.7.1.A Main Steam Safety Valves (MSSVs)

CRS Direct the Auxiliary Operator to verify steam from the MSSV in the penthouse area.

CRS Direct actions per ACA 1203.012F, for K07-C5.

CRS Direct the CBOR to begin a power reduction.

CBOR Using the ULD toggle switch, reduce load demand.

ROLE PLAY: Call as the AO and report steam coming from the MSSV piping and coming from the sides of the penthouse.

CRS Based on the severity of the steam leak, direct the crew to perform a reactor trip and carry out the immediate actions.

CBOR Depress the Reactor Trip P/B on C03, verify all rods inserted and reactor power dropping.

CBOT Depress the Turbine Trip P/B on C01, verify all governor valves and throttle valves close.

CBOT Recognize that a governor and throttle valve fail to close and position himself at C09 to perform MSLI for the affected OTSG. Report to the CRS the failure of the valves to close.

CRS Direct the CBOT to actuate MSLI for the affected OTSG.

-Continued-Page 12 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No: 2005-1 Scenario No: 4 (SPARE) Event No: 6, 7, 8 Event

Description:

Main steam safety valve associated with B OTSG experiences structural failure and lifts. Steam Leak significant to warrant manual reactor trip. The main turbine fails to fully trip when the unit is tripped. One governor valve and one throttle valve fail to close, requiring the crew to shut the MSIV from the affected OTSG. EFW valves to B OTSG from P7B fail open and will not close from the handswitches Time Position Applicants Actions or Behavior CBOT Actuate MSLI for the OTSG with the lowest pressure and EFW from the remote switch matrix on C09. Verify proper actuation per RT6.

EAL NUE 3.1 Uncontrolled OTSG Depressurization Resulting in MSLI Actuation CRS Transition to the Overcooling EOP, 1202.003 and provide direction to the crew.

CBOR Recognize the EFW valves to B OTSG from P7B have failed open and will not close using the controls on C09.

CRS Direct the CBOR to stop P7B after verifying P7A is operating properly.

CT CBOR Stop P7B by placing the handswitch on C09 in the P-T-L position.

CBOR When the B OTSG has boiled dry, verify and report the overcooling has been terminated CRS Transition to step 25 of Overcooling EOP and direct the crew to stabilize the plant.

SCENARIO TERMINATION B OTSG is depressurized, EFW flow to B OTSG is stopped, and overcooling is terminated.

OR As directed by the Lead Evaluator Page 13 of 13

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