Text

Final Operating Exam (Sections a, B, and C) (Folder 3)
	ML13098A271
Person / Time
Site:	Peach Bottom
Issue date:	02/25/2013
From:	; Exelon Generation Co
To:	Todd Fish; Operations Branch I
	Jackson D
Shared Package
ML12328A009	List: IR 05000277/2013301; ML12332A052; ML13079A497; ML13087A454; ML13098A252; ML13098A256; ML13098A262; ML13098A271; ML13154A285; ML13154A297; ML13154A319; ML13154A324;
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EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET Commo JPM D QUALIFICATION MANUAL OJT MODULE PLOR -337CA U,R,SS~~:;:;I LICENSED OPERATOR REQUALIFICATION 001 mda Lineup Standby Gas Treatment System for Automatic Operation - Alternate Path (Switches Are Out of Position)

APPROVALS:

Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: _ _----:I_ _~/_ __

NAME: ISSUE DATE:

Last First M,1.

EMPLOYEE 10#: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Sig nature/Date PLOR337CA Rev001 Page 1 of 8

EXELON NUCLEAR PEACH BODOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2610030101 - PLOR-337CA KiA: 261000 G2.1.29 URO: 4.1 SRO: 4.0 TASK DESCRIPTION: Knowledge of how to conduct system lineups, such as valves, breakers, switches, etc.

A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. ..IPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

PLOR337CA Rev001

B. TOOLS AND EQUIPMENT

1. Partial procedure COL 9A.1.A "Standby Gas Treatment System Automatic Operation",

Rev. 10. All steps are marked "NIA" except for step:

5 (A fan) 20 (AO 20469-01) 6 (8 fan) 21 (AO 20469-02)

8 (AO 2507) 22 (AO 20470-01) 9 (AO 2512) 23 (AO 20470-02) 10 (AO 2514) 24 (PO 20465) 11 (AO 2510) 25 (AO 20466) 16 (AO 00475-01) 17 (AO 00475-02) 18 (AO 00476-01) 19 (AO 00476-02)

C. REFERENCES

1. COL 9A.1.A "Standby Gas Treatment System Automatic Operation", Rev. 10.

D. TASK STANDARD

1. Satisfactory task completion is indicated when the Unit 2 Main Control Room related steps of COL 9A.1.A, A "Standby Gas Treatment System Automatic Operation", are complete.

2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to lineup the Unit 2 Main Control Room portion of the Standby Gas Treatment System using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. A Unit 2 startup is in progress.

2. Emergent maintenance was performed on various components of the Standby Gas Treatment System (SGTS).

3. Shift Management directs that a lineup verification of the Unit 2 Main Control Room portion of the SGTS be performed.

4. A partial of COL 9A.1.A "Standby Gas Treatment System Automatic Operation" has been reviewed and approved for use.

PLOR337CA Rev001 Page 3 of 8

G. INITIATING CUE The Control Room Supervisor directs you to perform an Independent Verification (IV) of the Unit 2 Main Control Room portion of the SGTS using the approved partial of COL 9A.1.A "Standby Gas Treatment System Automatic Operation". Do NOT manipulate any components.

PLOR337CA Rev001 Page 4 of 8

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD

- - - NOTE TO EVALUATOR****

Hand partial of COL 9A.1.A " Standby Gas Treatment System Automatic Operation" to the Examinee to start this JPM.

1 Verify Standby Gas Treatment Fan 'A' P On panel20C012 verify Standby Gas (OAV020) control switch is in "AUTO". Treatment Fan 'A' (OAV020) control switch is in "AUTO" position.

Initial and date the check off list step.

2 Verify Standby Gas Treatment Fan '8' P On panel 20C012 recognize that the (08V020) control switch is in "AUTO". Standby Gas Treatment Fan '8' (08V020) control switch is in the "PULL-TO-LOCK" (Cue: If notified that the Fan '8' (08V020) position and NOT in "AUTO" position.

control switch is NOT in "AUTO" position, acknowledge report. If necessary, direct May report to the Control Room candidate to continue task and report all Supervisor that the switch is out of target discrepancies upon completion of task.) position now or report all mispositionings after COL is completed.

Annotate as-found position of switch.

3 Verify AO-2507 "Drywell Outboard 18" P On panel 20C003-3 verify that AO-2507 Vent" is in "CLOSED" position. "Drywell Outboard 18" Vent" is in "CLOSED" position.

Initial and date the check off list step.

4 Verify AO-2512 "Torus Outboard 18" P On panel 20C003-3 verify that AO-2512 Vent" is in "CLOSED" position. "Torus Outboard 18" Vent" is in "CLOSED" position.

Initial and date the check off list step.

5 Verify AO-2514 "Torus Outboard 2" Vent" P On panel 20C484A verify that AO-2514 is in "CLOSED" position. "Torus Outboard 2" Vent" is in "CLOSED" position.

Initial and date the check off list step.

PLOR337CA Rev001 Page 5 of 8

STEP NO STEP ACT STANDARD 6 Verify AO-2510 "Drywell Outboard 2" P On panel 20C484B verify that AO-251 0 Vent" is in "CLOSED" position. "Drywell Outboard 2" Vent" is in "CLOSED" position.

Initial and date the check off list step.

7 Verify AO-00475-01 "Standby Gas P On panel20C012 recognize that AO Treatment A Filter Inlet" is in "AUTO" 00475-01 "Standby Gas Treatment A position. Filter Inlet" control switch is in the "CLOSE" position and NOT in "AUTO" position.

(Cue: If notified that the AO-00475-01 May report to the Control Room "Standby Gas Treatment A Filter Outlet" Supervisor that the switch is out of target is NOT in the "AUTO" position, position now or report all mispositionings acknowledge report. If necessary, direct after COL is completed.

candidate to continue task and report all discrepancies upon completion of task.) Annotate as-found position of switch.

8 Verify AO-00475-02 "Standby Gas P On panel20C012 recognize that AO Treatment A Filter Outlet" is in "AUTO" 00475-02 "Standby Gas Treatment A position. Filter Outlet" control switch is in "CLOSE" and NOT in the "AUTO" position.

May report to the Control Room (Cue: If notified that the AO-00475-02 Supervisor that the switch is out of target "Standby Gas Treatment A Filter Outlet" position now or report all mispositionings is NOT in the "AUTO" position, after COL is completed.

acknowledge report. If necessary, direct candidate to continue task and report all Annotate as-found position of switch.

discrepancies upon completion of task.)

9 Verify AO-00476-01 "Standby Gas P On panel 20C012 verify that AO-00476 Treatment B Filter Inlet" is in "AUTO" 01 "Standby Gas Treatment B Filter Inlet" position. is in "AUTO" position.

Initial and date the check off list step.

PLQR337CA Rev001 Page

STEP NO STEP ACT STANDARD 10 Verify AO-00476-02 "Standby Gas P On panel 20C012 verify that AO-00476 Treatment B Filter Outlet" is in "AUTO" 02 "Standby Gas Treatment B Filter position. Outlet" is in "AUTO" position.

Initial and date the check off list step.

11 Verify AO-20469-01 "Standby Gas P On panel20C012 recognize that AO-Treatment DM! Reactor Bldg Equipment 20469-01 "Standby Gas Treatment DM!

Exhaust" is in "CLOSED" position. Reactor Bldg Equipment Exhaust" is in the "CLOSED" position.

Initial and date the check off list step 12 Verify AO-20469-02 "Standby Gas P On panel 20C012 recognize that AO-Treatment DM! Reactor Bldg Equipment 20469-02 "Standby Gas Treatment DM!

Exhaust" is in "CLOSED" position. Reactor Bldg Equipment Exhaust" is in the "CLOSED" position.

Initial and date the check off list step 13 Verify AO-20470-01"Standby Gas P On panel 20C012 recognize that AO-Treatment Refuel Floor Exhaust" is in 20470-01 "Standby Gas Treatment "CLOSED" position. Refuel Floor Exhaust" is in the "CLOSED" position.

Initial and date the check off list step 14 Verify AO-20470-02 "Standby Gas P On panel 20C012 recognize that AO-Treatment Refuel Floor Exhaust" is in 20470-02 "Standby Gas Treatment "CLOSED" position. Refuel Floor Exhaust" is in the "CLOSED" position.

Initial and date the check off list step 15 Verify PO-20465 "Exhaust to Standby P On panel 20C012 recognize that PO-Gas Treatment Equipment Cell" is in 20465 "Exhaust to Standby Gas "CLOSED" position. Treatment Equipment Cell" is in the "CLOSED" position.

Initial and date the check off list step 16 Verify PO-20466 "Exhaust to Standby P On panel 20C012 recognize that PO-Gas Treatment Rx Bldg" is in "CLOSED" 20466 "Exhaust to Standby Gas position. Treatment Rx Bldg" is in the "CLOSED" position.

Initial and date the check off list step PLOR337CA Rev001 Page 7 of 8

STEP NO STEP ACT STANDARD 17 Inform Control Room Supervision of P Inform Control Room Supervision of completion of partial SGTS lineup. completion of partial COL 9A.1.A. A lineup verification of the Unit 2 Main Control Room portion of the SGTS has been performed.

18 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When a lineup verification of the Unit 2 Main Control Room portion of the SGTS has been performed the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

PLOR337CA Rev001 Page 8 of 8

TASK CONDITIONS/PREREQUISITES

1. A Unit 2 startup is in progress.

2. Emergent maintenance was performed on various components of the Standby Gas Treatment System (SGTS).

3. Shift Management directs that a lineup veri'fication of the Unit 2 Main Control Room portion of the SGTS be performed.

4. A partial of COL 9A.1.A "Standby Gas Treatment System Automatic Operation" has been reviewed and approved for use.

INITIATING CUE The Control Room Supervisor directs you to perform an Independent Verification (IV) of the Unit 2 Main Control Room portion of the SGTS using the approved partial of COL 9A.1.A "Standby Gas Treatment System Automatic Operation". Do NOT manipulate any components.

COL 9A.l.A Rev. 1C

- Page 1 of 10 MTW:mtw

£.OL_ 9A. l ..,.1L__ STANDBY GAS TREATMENT SYSTEM AUTOMATIC OPERATION

Purpose:

Lineup the Standby Gas Treatment System for Automatic Operation.

STEP TARGET CHECKED

APPARATUS POSITION LOCATION BY DATE

1. Throttle HV-0-36B-18870A and verify FI-7130A, "SBGTS A Train Purge Air Flow", located on the sidf; of A SBGT filter train, indicates 30-40 SCFH.

Throttle HV-0-36B-18870B and vcd fy FI-7130B, I1SBGTS B Train Purge Air Flow", located on the side of B SBGT filter train, indicates 30-40 SCFH.

3. HCS 00522-01 Open OBC452 Standby Gas Bypass PO Control

4. HCS 00530 Closed OBC452 Standby Gas Vortex PO Control CY

~'

['

.) . Verify Standby Gas Treatment A Fan OAV020 control switch, located on Panel 20C012, is in 11 AUTO " .

Verify Standby Gas Treatment B Fan OBV020 control switch, located on Panel 20C012, is in 11 AUTO " .

Verify Standby Gas Treatment C 'f!'an OCV020 control switch, located on Panel 30C012, is in "AUTO". _AJ!fL___

AO 2507 Closed 20C003-3 Drywell Outbd 18" Vent

COL 9A.l.A Rev. 10 Page 2 of 10 STEP TARGET CHECKED

APPARATUS POSITION LOCATION BY DATE Q 9. AO 2512

'rorus Outbd 18" Vent Closed 20COO3-3 (52) AO 2514 Outbd 2" Torus Vent Closed 20C484A

--~-.-

AO 2510 Closed 20C484B Outbd 2" Drywell Vent -----.~--

'12. AO 3507 Closed 30C003-3

, Drywell Outbd 1S" Vent AliA:

t~~

I~ 13. AO 3512 Closed 30C003-3 f

I~

AI Torus Outbd 18" Vent tJ/K_.___

f

14. AO 3514 Closed 30C484A

\

.JJiA:-.----

Outbd 2" Torus Vent IS. AO 3510 Outbd 2" Drywell Vent Closed 30C484B

__jrL __._

G AO 00475,- 01 Standby Gas Treatment A Filter Inlet Auto 20C012 C3 AO 00475-02 Standby Gas Treatment A Filter Outlet Auto 20C012 C9

/1.8.

/1 AO 00476-01 Standby Gas Treatment B Filter Inlet Auto 20C012 d "

'--'"\

AO 00476-02 Standby Gas Treatment B Filter Outlet Auto 20C012

._----- -----~----"~ -, --'---'--'~--

V AO 20469-01 Standby Gas Treatment D/w Rx Bldg Equip Exh Closed 20C012 CP AO 20469-02 Standby Gas Treatment D/w Rx Bldg Equip Exh Closed 20C012

--~-- -'~--'--" -----~ --------.

COL 9A.l.A Rev. 10 Page 3 of 10 STEP TARGET CHECKED

APPARATUS POSITION LOCATION BY DATE

/~ AO 20470-01 Closed 20C012 B' Standby Gas Treatment Refuel FIr Exh AO 20470-02 Closed 20C012 Standby Gas Treatment Refuel FIr Exh PO 20465 Closed 20C012 Exh to Stby Gas Treat Equip Cell PO 20466 Closed 20C012 Exh to Stby Gas Treat Rx Bldg f 26. AO 30469-01 Closed 30C012 SLandby Gas Treatment D/W Rx Bldg Equip Exh

27. AO 30469-02 Closed 30C012 Standby Gas Treatment D/W Rx Bldg Equip Exh

28. AO 30470-01 Closed 30C012 Standby Gas Treatment Refuel FIr Exh

29. AO 30470-02 Closed 30C012

/,~ Standby Gas Treatment Refuel FIr Exh

30. PO 30465 Closed 30C012 Exh to Stby Gas Treat Equip Cell

31. PO 30466 Closed 30C012 Exh to Stby Gas Treat Rx Bldg

32. BKR 52-5923 Closed E124-T-B Stby Gas Treatment Fan OAV20

33. BKR 52-5944 Closed E124-T-B Stby Gas Treatment Exht Ht OAE65

34. BKR 52 6043 Closed E224-T-B B Emer Stby Gas Treat Fan OBV20

COL 9A.1.A Rev. 10 Page 4 of 10 STEP TARGET CHECKED

APPARATUS POSITION LOCATION BY DATE

35. BKR 52-6023 Closed E234-T-B 36.

Stand-by Gas Treatment Exhaust Preheat OBE65 BKR 52-3894 Closed E334-R.-B rJ!Jl Stand-by Gas Treat Exh OCV20 _._--

3'7. RTV 0 9A 20008H Open R/W-8 F'T-20008 Hi --~--.-

38. RTV 0 9A 20008L Open R/W-8 F'r ;WOO8 Low -~,------,

39. RTV 0 9A 668H Open OCC452 DPI-00668-01 +

DPI-00668-02 Exhaust to Stack FE-2000B - - - _. --~-.-

40. R'TV 0 9A 668L Open OCC452 DPI-00668-01 +

DPI-00668-02 Exhaust to Stack FE-2000B

41. RTV 0 9A 20001H Open R/W-l DPS-20001/DPT-20001 Hi Filter Train A Inlet Plenum

--~~- .. --"

42. RTV 0 9A 20001L Open R/W-l DPS-20001/DPT-20001 Lo Fltr Train A Outlet Plenum

43. RTV 0 9A 20002-01 Open R/W-l DPI-20002-01 Lo +

20002-02 Hi Dnstrm OBF034 Upstrm OBF035 -,------

44. RTV 0 9A 20002-02 Open R/W-l DPI-20002-02 Lo +

20002-03 Hi Dnstrm OBF035 Upstrm OBF036 -----_. --~-.--.---

~..

~,

1i5. RTV 0 9A 20002-03 DPI-20002-03 Lo +

20002-04 Hi Dnstrm OBF036 Upstrm OBF037 Open R/W-l Jtt_____

COL 9A.l.A Rev. 10 Page 5 of 10 STEP TARGET CHECKED

APPARATUS POSITION LOCATION BY DATE Open R/W-1 JI+

4G. R'rv 0 9A 20002H DPS-20002/DPT-20002 Hi Filter Train B Inlet Plenum ---- .---'"\ ----~--

47. RTV 0 9A 20002L Open R/W-1 DPS-20002/DPT-20002 Lo Fltr Train B Outlet Plenum

48. HV-O-09A-11428A Closed & R/W-l SBGT Exhaust Fan A Capped Disch Spare

49. HV-0-09A-11427A Closed & R/W-1 SBGT Exhaust Fan A Capped Suction Spare

50. HV-0-09A-11428C Closed & R/W-1 SBGT Exhaust Fan C Capped Disch Spare

51. HV-0-09A-11427C Closed & R/W-1 SBGT Exhaust Fan C Suction Spare

52. RTV 0 9A 20001-01 Open R/W-l DPI-20001-01 Lo +

20001-02 Hi Dnstrm OAF034 Upstrm OAF035

53. RTV 0 9A 20001-02 Open R/W-1 DPI-20001-02 Lo +

20001-03 Hi Dnstrm OAF035 Upstrm OAF036

54. RTV 0 9A 20001-03 Open R/W-l DPI-200QI-03 Lo +

20001-04 Hi Dnstrm OAF036 Dpstrm OAF037

55. HV 2 36B 20475-01 Open R2-53 Hi-Rad Opening A/S

~.--y---------_.

Blocked to DPC-20479-01 +

PO-20477-01

56. HV 2 36B 20476-01 Open R2-53

__AlJL__

Hi-Rad Opening A/S Metering Valve to PO-20477-01

COL 9A.l.A Rev. 10 Page 6 of 10 STEP TARGET CHECKED fj APPARATUS POSITION LOCATION BY DATE:

HV 2 36B 20475-02 Open R2-S2 Hi-Rad Opening A/S 58.

Block to DPC-20479 02

+ PO-20477-02 HV 2 36B 20476-02 Open R2-S2 Iv!!+

Hi-Rad Opening Als Metering Valve to PO-7.0477-02

59. HV 3 36B 30475-01 Open R3-53

~

Hi.-Rad Opening Als Block to DPC-304'l9-01

+ PO,* 3 0477 - 01 ---- - - " -...

~

-~~"-

i60, HV 3 36B 30476-01 Open R3-53 i

Hi **Rad Opening A/s Metering Valve to PO-30477-01 I

,6l. HV 3 36B 30475-02 Open R3-S2 Hi-Rad Opening Als Block to DPC**30479-02

+ PO-30477-02 -.--~*-~---- ~.- ....

62. HV 3 36B 30476-02 Open R3-S2 Hi-Rad Opening AIS Metering Valve to PO-30477-02 _ _ w _ _ _ ~ ** _ _

t 10 ____0____

INSTRUMENT VALVES

-- ._--_ .. -~----

TIV 0 9A 20001H Open R/W-l DPS-20001 High Process Side Filter Train A Inlet Plenum

64. lIV 0 9A 20001L Open R/w-1 DPS-20001 Low Process Side FItr Train A Outlet Plenum ______'Y _____.. _ _ _

6!) . lTV 0 9A 20002H Open R/w-l DPS-20002 High Process Side Filter Train B Inlet Plenum iPr

___._M_. -~ J _____._

COTJ 9A. 1. A Rev. 10 Page 7 of 10 STEP TARGET CHECKED

APPARATUS POSITION LOCATION BY DATE

66. TTV 0 9A 20002L Open R/W-l DPS-20002 Low Process Side FItr Train B Outlet Plenum

67. 1 IV 0 9A 11429H Open R/W-l DPT-20002 High Process Side Filter Train B Inlet Plenum

68. IJV 0 9A 11429L Open R/W-l DPT-20002 Low Process Side Fltr Train B Outlet Plenum

69. ISV-2-9A-20003-01L Open R2 53 DPT-20003-01 Low Side Instrument Shutoff Valve

70. ISV-2-9A-20003-01H Open H2-53 DPT-20003-01 High Side Instrument Shutoff Valve

71. IEV-2-9A-20003-01 Closed R2-53 DPT-20003-01 Equalization Valve

72. IDV-2-9A-20003-01H Closed & R2-53 DPT-20003-01 High Capped Side Instrument Drain Valve

73. IDV-2-9A-20003-01L Closed & R2-53 DPT-20003-01 Low Capped Side Instrument Drain Valve

74. ISV-2-9A-20003-02L Open R2-56 DPT-20003-02 Low Side Instrument Shutoff Valve

'] 'S

ISV-2-9A-20003-02H Open R2-56 DPT-20003-02-High Side Instrument Shutoff Valve

COL 9/L I .11, Rev. 10 Page 8 of ] 0 STEP TARGET CHECKED

APPARATUS POSITION LOCATION BY DATE

76. IEV-2-9A-20003-02 Closed R2-56 DPT-20003-02 Equalization Valve ~-- ~ ..

77. IDV-2-9A-20003 02H Closed & R2-56 DP'I'-20003-02 High Capped Side Instrument Drain Valve -- .. ,~,--

78. IDV-2-9A-20003-02L Closed & R2-56 DP'I'-20003-02 Low Capped Side Instrument Drain Valve -----"

79. ISV-3-9A-30003 OIL Open R3-53 DP'l'-30003-01 Low Side Instrument Shutoff Valve ---~-.-- ---

80. ISV-3-9A-30003-0IH Open R3-53 DPT-30003-01 High Side Instrument Shutoff Valve -_ _._----_.

81. IEV-3-9A-30003-01 Closed R3-53 DPT-30003-01 Equalization Valve - - - - , - -

82. IDV-3-9A-30003-0IH Closed & R3 53 DPT-30003-01 High Capped Side Instrument Drain Valve

83. IDV-3-9A-30003-01L Closed & R3 53 DPT-30003-01 Low Capped Side Instrument Drain Valve

_ _ _ _ w_~ _ _ ~"' **

84. ISV-3-9A-30003-02L Open R3-57 DPT-30003-02 Low Side Instrument Shutoff Valve

85. ISV-3-9A-30003-02H Open R3-S7 DPT-30003-02 High Side Instrument Shutoff Valve \v

---~ ~-----

__ fJ {l~~-"

86. IEV-3-9A-30003-02 Closed R3-S7 DPT-30003-02 Equalization Valve

COI, 9A.l.A Rev. 10 Page 9 of 10 STEP TARGET CHECKED

APPARA'l'US POSITION LOCATION BY DATE

87. IDV-3-9A-30003-02H Closed & R3-57 DPT-30003-02 High Capped Side Instrument Drain Valve

88. IDV-3-9A-30003 02L Closed & R3 57 DPT-30003-02 Low Capped Slde Instrument Drain Valve 20C003-3 - U/2 CS, RHR, Isol & Blowdown Ctrl Board 20C012 - Plant Services Console

>'OC484A Unit 2 CAD Control Board 20C484B .. Unit 2 CAD Control Board 30C00'3-3 . U/3 CS, RHR, Is01 & Blowdown Ctrl Board 30C012 - Plant Services Console 30C484A .- Unit 3 CAD Control Board 10C484B . Unit 3 CAD Control Board E124 'I'-B - Unit 2 Turbine Bldg Across from E12 Bus E224-T-B - Unit 2 Turbine Bldg Near E22 Bus Room 8234-T-B - Unit 3 Turbine Building F!334-R-B - Unit 3 Northwest Corner Reactor Bldg OBC452 - SBGT Exhaust Fan Bypass Damper/Vortex Vane Control PdrH:~ I OCC4~)2 SBGT Room Panel R/W-l - Standby Gas Treatment Room R/W-* 8 - Waste and Floor Drain Surge Tank Room R2-S2 - Reactor Building Fan Area - Elev. 214' R2-53 - Rx Bldg Hallway - Elevation 195 ft.

R3-*52 - Reactor Building Fan Area - Elev. 214' R3-53 - Rx Bldg Hallway - Elevation 195 ft.

R2-56 - Rx Bldg SE General Area - Elevat:ion 234 ft.

R3-S7 - Rx Bldg NE General Area - Elevation 234 ft.

AO - Air Operated Valve BKR - Breaker Compartment RCS - Hand Control Switch IDV - Instrument Drain Valve lEV .. Instrument Equalizing Valve TIV - Instrument Isolation Valve ISV - Instrument Shutoff Valve RMS .- Control Room Hand Switch (Remote)

RTV - Root Valve

COL 9A.l.A Re'",. 10 Page 10 of 10 SIGNATURE SECTION:

PRINT NAME INITIALS Completed Lineup reviewed in accordance with the Operators Manual, IIProcedure Use ll Section.

by Shift Management

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET 4!21"'t'\ Bottom QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR REQUALIFICATION 00 J, A. Verbillis jav Evaluate Overtime Work Request APPROVALS:

Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: _ _ _' _ _ _' _ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE 10#: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

SI~(lature/Da{e PLOR279C RevOOO

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE:

Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2991120301 - PLOR-279C KIA: G2.1.5 URO: 2.9 SRO: 3.9 TASK DESCRIPTION: Ability to use procedures related to shift staffing, such as minimum crew complement, overtime limitations, etc.

A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this ..IPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, ;s not to be given to the examinee.

PLOR279C RevOOO Page 2 of4

B. TOOLS AND EQUIPMENT

1. LS-AA-119 "Fatigue Management and Work Hour Limits" C. REFERENCES

1. LS-AA-119 "Fatigue Management and Work Hour Limits" Rev 9 D. TASK STANDARD

1. Satisfactory task completion is indicated when the candidate successfully assesses the work hour limits and documents findings on the cue sheet.

2. Estimated time to complete: 20 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to review the work history provided, determine whether or not you are able to cover the requested shift AND determine if any work hour limits have already been Violated, using appropriate procedures. I will describe initial conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Shift supervision has contacted you on Saturday, 2/16 (a scheduled day off), requesting you cover a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months overtime shift from 0700 to 1900.

2. You were on vacation for two weeks, returning to work on Sunday, 2/3.

3. Your work history for the previous two weeks is as follows, with all hours having been in posted Licensed Reactor Operator positions.

Sunday Monday Tuesday Wednesday Thursday Friday Saturday 2/3 2/4 2/5 2/6 217 I 2/8 2/9 I Worked Worked OFF OFF Worked Worked OFF 1900 - 0700 1900 - 0700 I I 1900 -1100 1900 - 0700 Sunday I Monday Tuesday Wednesday Thursday Friday Saturday I 2/10 2/11 2112 I 2/13 I 2/14 2/15 2/16_

Worked Worked Worked Worked Worked Worked Request:

I I 0700 - 1900 0700 - 1900 0700 - 1900 I 0700 -1900 I 0700 -1900 0700 - 1900 I 0700 to 1900 G. INITIATING CUE Using the work history provided:

1. Determine whether or not you are able to cover the requested shift AND whether any work hours limits have already been violated.

2. Document your results on the Cue sheet provided.

PLOR279C RevOOO Page 3 of 4

H. PERFORMANCE CHECKLIST Evaluator Cue:

Provide candidate with copy of LS-AA-119 "Fatigue Management and Work Hour Limits" procedure and Cue Sheet.

1 Review work history and LS-AA-119 to P I Candidate reviews procedure for Work

! determine if able to work requested shift.

Hour limits and reviews work history provided.

2 Determine that working the requested P Determine that working the requested overtime shift will result in exceeding shift would result in exceeding 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in work hour limits. any 7-day period (Sunday, 2/10 through Friday, 2/15 shows 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months worked.

Working Saturday would result in exceeding 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in the 7-day period)

3 Determine that the previously worked P Determine that the break between shifts schedule violates additional work hour from Thursday 217 to Friday 2/8 was less rules. (Cue: If asked, report that the than the required 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months .

transition from 2n to 2/8 is NOT a scheduled transition for the crew) 4 Inform supervision (via documenting on P Document findings on cue sheet.

cue sheet) that you are not able to work the requested overtime shift due to 5 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND

procedures.

Under "ACT" P - must perform I. TERMINATING CUE When review is complete and supervision has been notified (cue sheet complete) the evaluator will terminate the exercise.

PLOR279C RevOOO

TASK CONDITIONS/PREREQUISITES

1. Shift supervision has contacted you on Saturday, 2/16 (a scheduled day oft),

requesting you cover a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months overtime shift from 0700 to 1900.

2. You were on vacation for two weeks, returning to work on Sunday, 2/3.

3. Your work history for the previous two weeks is as follows, with all hours having been in posted Licensed Reactor Operator positions.

Thursd~ I I I Sunday Monday i Tuesday Wednesday Friday Saturday I 2/3 I 2/4 2/5 2/6 217 I 2/8 I

I 2/9 i

Worked Worked OFF OFF i Worked Worked i OFF I

1900 -0700 1900 - 0700 I I 1900 - 1100 i 1900 - 0700 I Sunday Monday Tuesday !

Wednesday !

Thursday Friday Saturday I 2110 2/11 2/12 2/13 2/14 I 2115 2116 I I Worked Worked Worked Worked Worked Worked Request:

I 0700 - 1900 I 0700 - 1900 I 0700 - 1900 i 0700 - 1900 i 0700 - 1900 0700 - 1900 0700 to 1900 I INITIATING CUE Using the work history provided:

1. Determine whether or not you are able to cover the requested shift AND whether any work hours limits have already been violated.

2. Document your results below.

++++++++++++++++++++++++++++++++++++++++++++++++

Circle One: CAN / CANNOT work the requested shift.

Reason:

Additional Violations (if any):

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET ommon I

~ JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING PLOR-274C Licensed Operator Requalification 000 C. N. Croasmun cnc ISOLATING THE 3B RBCCW HEAT EXCHANGER DUE TO A LEAK APPROVALS:

Title Signature I Title Date Signature I Title Date

APPROVED FOR USE:

Signature f Title Date EFFECTIVE DATE: _ _---',_ _ _,_ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE ID#: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date PLOR274C RevOOO Page 1 of 6

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 20023004011 PLOR-274C KIA: G2.2.41 RO: 3.5 TASK DESCRIPTION: Ability to obtain and interpret station electrical and mechanical drawings A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this ..IPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

PLOR274C RevOOO Page 2

B. TOOLS AND EQUIPMENT

1. A Full Set of each of the following P & IDs:

a. M-314 series

b. M-315 series

c. M-316 series C. REFERENCES

1. P&ID M-316 sheet 3, Rev. 52

2. P&ID M-314 sheet 8, Rev. 65

3. P&ID M-315 sheet 4, Rev. 54

4. OP-AA-108-101 "Control of Equipment and System Status" D. TASK STANDARD

1. Satisfactory task completion is indicated when the isolation points and vent/drain paths for the RBCCW, Service Water, and Emergency Service Water side of the 3B RBCCW heat exchanger have been identified.

2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, determine the isolation points, vent paths, and drain paths necessary to isolate a tube leak located on the 3B RBCCW heat exchanger.

F. TASK CONDITIONS/PREREQUISITES A suspected tube leak has been identified on the standby 3B Reactor Building Closed Cooling Water (RBCCW) heat exchanger 3BE018. The Work Control Supervisor will be developing an Abnormal Component Position Sheet for isolation, venting, and draining of the 3B RBCCW heat exchanger.

G. INITIATING CUE The Control Room Supervisor directs you to identify the components and their required positions to isolate, vent and drain the tube and shell side of the 3B RBCCW heat exchanger.

Document your results on the CUE SHEET.

PLOR274C RevOOO Page 3 of6

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Locate the component that is leaking on P Locate 3BE018 on M-316 sheet 3, P&ID drawings M-316 sheet 3 (RBCCW (Coordinates B-3) and on M-314 sheet 8 side) and M-314 sheet 8 (Service Water (Coordinates F-3).

side).

(Cue: Provide the candidate(s) with a full set of the M-314, M-31S and M-316 series P & IDs)

(Cue: If asked, inform candidate(s) that PIMS is down for IT maintenance)

I

- - NOTE ***

It should be determined by the Examinee that isolation points are selected first and then vents and drains are to be opened. This applies to both the RBCCW and Service Water sides of the heat exchanger.

2 Close HV-3-3S-3420SB "RBCCW HX P Identifies that HV-3-3S-3420SB "RBCCW 3BE018 Inlet Block Valve". HX 3BE018 Inlet Block Valve" must be CLOSED in order to ISOLATE RBCCW to the heat exchanger.

3 Close HV-3-3S-34210B "RBCCW HX P Identifies that HV-3-3S-3421 OB "RBCCW 3BE018 Outlet Block Valve". HX 3BE018 Outlet Block Valve" must be CLOSED in order to ISOLATE RBCCW to the heat exchanger.

4 Open HV-3-3S-34206B "RBCCW HX P Identifies that HV-3-3S-34206B "RBCCW 3BE018 Drain Valve" HX 3BE018 Drain Valve" must be OPENED in order to DRAIN the RBCCW side of the 3B RBCCW heat exchanger.

PLOR274C RevOOO

5 Open HV-3-35-34209B "RBCCW HX P Identifies that HV-3-35-34209B "RBCCW 3BE018 Lower Vent Valve" HX 3BE018 Lower Vent Valve" must be OPENED in order to VENT the lower section of the 3B RBCCW heat exchanger AND/OR AND/OR HV-3-35-34207B "RBCCW HX 3BE018 Open HV-3-35-34207B "RBCCW HX Upper Vent Valve" must be OPENED in 3BE018 Upper Vent Valve" order to VENT the upper section of the

3B RBCCW heat exchanger.

6 Close HV-3-30-31866B "Service Water P Identifies that HV-3-30-31866B "Service Inlet to B RBCCW HX Block Valve". Water Inlet to B RBCCW HX Block Valve" must be CLOSED in order to ISOLATE Service Water to the heat exchanger.

7 Close HV-3-30-31867B "Service Water P Identifies that HV-3-30-31867B "Service Outlet from B RBCCW HX Block Valve". Water Outlet from B RBCCW HX Block Valve" must be CLOSED in order to ISOLATE Service Water to the heat I

exchanger.

8 Close HV-3-33-520B "ESW to RBCCW Identifies that HV-3-33-520B "ESW to HX 3BE018 Inlet Block Valve". RBCCW HX 3BE018 Inlet Block Valve" must be CLOSED in order to ISOLATE Emergency Service Water to the heat exchanger.

9 Open HV-3-30-31868B "B RBCCW HX P Identifies that HV-3-30-31868B "B Tube Side Inlet Drain Valve"

RBCCW HX Tube Side Inlet Drain Valve"

must be OPENED in order to DRAIN the Service Water side of the 3B RBCCW heat exchanger.

10 Open HV-3-30-31869B "B RBCCW HX P Identifies that HV-3-30-31869B "B Tube Side Low Point Drain Valve" RBCCW HX Tube Side Low Point Drain I Valve" must be OPENED in order to

DRAIN the Service Water side of the 3B RBCCW heat exchanger.

11 Open HV-3-30-70B "B RBCCW HX Tube P Identifies that HV-3-30-70B "B RBCCW Side High Point Drain Valve" HX Tube Side High Point Drain Valve" must be OPENED in order to DRAIN the Service Water side of the 3B RBCCW heat exchanger.

PLOR274C RevOOO

12 Open HV-3-30-71B "B RBCCW HX Tube P Identifies that Open HV-3-30-71 B "B Side Vent Valve" RBCCW HX Tube Side Vent Valve" must be OPENED in order to VENT the Service Water side of the 3B RBCCW heat exchanger.

13 Inform Control Room Supervisor of task P The operator informs the Control Room completion. Supervisor of task completion.

(Cue: The Control Room Supervisor acknowledges the report.)

14 As an evaluator ensure that you have P Positive control established.

positive control of all exam material

! provided to the examinee (Task

! ConditionsIPrerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the RBCCW, Service Water and Emergency Service Water isolation points, vent paths, and drain paths to the 3B RBCCW heat exchanger have been identified, and the Control Room Supervisor informed, the evaluator will terminate the exercise.

PLOR274C RevOOO

TASK CONDITIONS/PREREQUISITES A suspected tube leak has been identified on the standby 3B Reactor Building Closed Cooling Water (RBCCW) heat exchanger 3BE018. The Work Control Supervisor will be developing an Abnormal Component Position Sheet for isolation, venting, and draining of the 3B RBCCW heat exchanger.

INITIATING CUE The Control Room Supervisor directs you to identify the components and their required positions to isolate, vent and drain the tube and shell side of the 3B RBCCW heat exchanger. Document your results on this CUE SHEET:

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET each Bottom 1 imerick D

~ JPM D QUALIFICATION MANUAL D OJT MODULE LICENSED OPERATOR TRAINING PLOR-244C LICENSED OPERATOR REQUALIFICATION 002 M. J. Kelly jav

. TI:rLE: PERFORM REACTOR COOLANT LEAKAGE SURVEILLANCE APPROVALS:

Signature I Title Date Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: _ _---' _ _ _ _ __

NAME: ISSUE DATE:

Last First M.I.

EMPLOYEE 10 NO. COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Sig nature/Date PLOR244C Rev002 Page 1 of6

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2690010201/ PLOR-244C KIA: G2.3.14 URO: 3.4 SRO: 3.8 TASK DESCRIPTION: PERFORM REACTOR COOLANT LEAKAGE TEST A NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

PLOR244C Rev002 Page 2 of6

B. TOOLS AND EQUIPMENT

1. AT2 -In-progress ST-0-020-560-2, Rev. 13, "Reactor Coolant Leakage Test"

2. Calculator C. REFERENCES

1. ST-0-020-560-2, Rev. 13, "Reactor Coolant Leakage Test"

2. AT3 - ST-0-020-560-2 Data Sheet 1 ANSWER KEY D. TASK STANDARD

1. Satisfactory task completion is indicated when reactor coolant leakage has been calculated using Data Sheet 1 of ST-0-020-560-2 "Reactor Coolant Leakage Test".

2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to calculate reactor coolant leakage using ST-0-020-560-2 "Reactor Coolant Leakage Test". I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Unit 2 is at 100% power.

2. The Unit 2 Drywell Sump Monitoring System is operable.

3. Unit 2 Drywell Floor Drain Sump valves and pumps are lined up in accordance with SO 20A.1.A, "Floor Drain Sumps Startup and Normal Operation".

4. Unit 2 Drywell Equipment Drain Sump valves and pumps are lined up in accordance with SO 20C.1.D, "Equipment Drain Sumps Startup and Normal Operation".

5. AO 2A.16-2 "Manual Adjustment of Recirculation Pump Seal Second Stage Pressure" has NOT been performed.

6. The previous week's flow data readings of Drywell Floor and Equipment Drain Sumps have been entered on Data Sheet 1 of ST-0-020-560-2,"Reactor Coolant Leakage Test".

7. The current 4-hour Drywell Floor Drain and Equipment Drain sump integrator readings have already been documented on Data Sheet 1 of ST-0-020-560-2,"Reactor Coolant Leakage Test".

8. All steps of ST-0-020-560-2,"Reactor Coolant Leakage Test", up to and including step 4.4.15, have been completed satisfactorily.

G. INITIATING CUE The Control Room Supervisor directs you to determine the Unit 2 reactor coolant leakage flow rate by performing steps 6.1 through 6.4 of ST-O-020-560-2,"Reactor Coolant Leakage Test".

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE DATA SHEET 1 DRYWELL FLOOR AND EQUIPMENT DRAIN SUMP LEAKAGE Date Day I Floor Drain (a) (b) (e) (d) (e) Equip Drain (fj (g) (h) All Data All time Sump 4 hr Flow 24 Hr 24 Hrs 24 hr Sump 4 hr Flow Total Within Cales Integ gpm Runn Runn Runn avg Integ gpm Leakage Aeeep Veri!

Flow Integ Dill Avg.

Flow Avg. Flow for .

Dill Flow Integ Dill 24 hr avg Crit (Initial)

Correct Reading <:5 gpm 24 Hrs <:2gpm Reading Sat unsat (Initial)

Ago <: 25 gpm SatlOOOO NlA NIA NlA NIA NlA NfA NlA NlA N/A N/A NIA

_1_1 0

SatlO400 NIA NIA 0 0 NlA NlA NlA NfA 1.42 NIA N/A NIA SatlO800 N/A NfA NlA NlA NlA NIA NIA 0 0 1.33 NIA NlA Satl1200 NlA NIA NlA NlA NlA N/A NIA NIA NIA 0 0 1.42 Satl1600 N/A NlA NlA NlA NlA N/A NIA NlA 0 0 1.67 NIA Satl2000 NlA NlA NfA NfA 904078 0 0 NlA 1400761 NlA 0.83 NIA

'TO<D)I f}"

Sun/OOOO 904078 0 0 0 0 0 1400780 19 1.58 1.38

. 1m...... IV Sun/O400

-0 -

IV Sun/O800

-0 -

IV Sunl1200

-0 IV Sun/1600

,-0 -

IV Sun/2000

-0 -

IV ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Cue: Hand the Candidate AT2, in- P I progress ST 020-560-2," Reactor Coolant Leakage Test" with some data recorded on Data Sheet 1

2 Calculate and record Drywell Floor Drain P Subtract the latest Floor Drain Sump 4-hour integrator difference. Integrator reading from the previous 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months reading. Place a "0" in column (a) of Data Sheet 1.

3 Calculate and record Drywell Floor Drain P Divide the number from column (a) of flow in gallons per minute. Data Sheet 1 by 12. Place a "0" in column (b) of Data Sheet 1.

4 Calculate and record the Drywell Floor P Add the six flow numbers from Column Drain 24-hour running average flow. (b) and divide by 6. Place a "0" in column (c) of Data Sheet 1.

5 Record 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months running average flow P Record a "0" in column (d) of Data Sheet Drywell Floor Drain for 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ago. 1.

6 Calculate and record the Drywell Floor P Subtract column (d) from column (c) on Drain 24-hour running average difference. Data Sheet 1. Place a "0" in column (e) on Data Sheet 1.

7 Calculate and record Equipment Floor P Subtract the latest Equipment Drain Drain 4-hour integrator difference. Sump Integrator reading from the previous 4-hour reading. Place a "19" in column (f) of Data Sheet 1.

8 Calculate and record Drywell Equipment P Divide the number from column (f) of Drain flow in gallons per minute. Data Sheet 1 by 12. Place a "1.58" in column (g) of Data Sheet 1 .

Cue: If examinee stalls here (step 6.2.3 of the surveillance test) state "You have adequate information on task conditions."

9 Calculate and record Total Drywell P Add the six Floor Drain numbers from Leakage. column (b) to the six Equipment Drain numbers from column (g) of Data Sheet 1.

Divide the above number by 6 and place a "1.38" in column (h) of Data Sheet 1.

PLOR244C RevOO2 Pag' 50f6

STEP NO STEP ACT STANDARD

10 Verify the following data is acceptable: P Verify all data is below the specified limits and initial "All Data Within Accep Crit" Column (b) is ~ 5.0 gpm Column of Data Sheet1 as SAT.

Column (e) is ~ 2.0 gpm

Column (h) is ~ 25.0 gpm 11 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND

procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When step 6.4 of ST-O-020-560-2,"Reactor Coolant Leakage Test" has been completed the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

PLOR244C Rev002 Page 6 at6

TASK CONDITIONS/PREREQUISITES

1. Unit 2 is at 100% power.

2. The Unit 2 Drywell Sump Monitoring System is operable.

3. Unit 2 Drywell Floor Drain Sump valves and pumps are lined up in accordance with SO 20A.1.A, "Floor Drain Sumps Startup and Normal Operation".

4. Unit 2 Drywell Equipment Drain Sump valves and pumps are lined up in accordance with SO 20C.1.D, "Equipment Drain Sumps Startup and Normal Operation".

5. AO 2A.16-2 "Manual Adjustment of Recirculation Pump Seal Second Stage Pressure" has NOT been performed.

6. The previous week's flow data readings of Drywell Floor and Equipment Drain Sumps have been entered on Data Sheet 1 of ST-0-020-560-2,"Reactor Coolant Leakage Test".

7. The current 4-hour Drywell Floor Drain and Equipment Drain sump integrator readings have already been documented on Data Sheet 1 of ST-0-020-560..2,"Reactor Coolant Leakage Test".

8. All steps of ST..O-020..560-2,"Reactor Coolant Leakage Test", up to and including step 4.4.15, have been completed satisfactorily.

INITIATING CUE The Control Room Supervisor directs you to determine the Unit 2 reactor coolant leakage flow rate by performing steps 6.1 through 6.4 of ST 020-560-2," Reactor Coolant Leakage Test" .

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET

~ JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING PLOR-259C LICENSED OPERATOR REQUALIFICATION 003 M. J. Kelly jav Review and Evaluate Reactor Coolant Chemistry Limits APPROVALS:

Signature I Title Date Signature I Title Date Signature f Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: _ _ _~ _ _ _ _ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE ID#: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date II PLOR259C Rev003

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Senior Reactor Operator TASK-JPM DESIGNATOR: 34431004021 PLOR-259C KIA: 2.1.34 SRO: 3.5 TASK DESCRIPTION: Knowledge of primary and secondary plant chemistry limits A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

PLOR259C Rev003

B. TOOLS AND EQUIPMENT

1. CH-10 "Chemistry Goals"

Provide candidate blank copy of procedure

Fill out four separate CH-10-1 Chemistry Recommendation Forms using Attachment 2 of this JPM as a reference. One form for reactor water, the other three are for A, B, and C condensate pump discharge.

2. ON-126 "High Condensate Conductivity" (give access to if requested)

3. TRM 3.9, RCS Chemistry (give access to if requested)

C. REFERENCES

1. CH-10, Rev. 16, "Chemistry Goals"

2. ON-126, Rev. 3, "High Condensate Conductivity"

3. TRM 3.9, RCS Chemistry D. TASK STANDARD

1. Satisfactory task completion is indicated when ON-126 "High Condensate Conductivity" reactor coolant chemistry actions and Technical Requirements Manual (TRM) Action Levels are determined in response to a condenser tube leak.

2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to determine immediate plant impact and compensatory measures, if any, for identified system chemistry limits using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Unit 2 has been at 100% power for 160 days.

2. The Hydrogen Water Chemistry System is in service.

3. Chemistry has delivered four CH-10-1 Chemistry Recommendation Forms related to Unit 2 condensate conductivity and Reactor Water chloride concentration.

4. PMS conductivity values match values provided on the CH-10-1 forms.

5. All the samples have been verified.

PLOR259C Rev003

G. INITIATING CUE The Shift Manager directs you to determine what immediate plant and/or Technical SpecificationlTRM/ODCM actions, if any, exist for the above conditions.

PLOR259C Rev003 Page 4 of6

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD

- - - NOTE TO EVALUATOR****

Provide all four CH-10-1 forms to the Examinee at the start of the JPM.

- - - NOTE TO EVALUATOR****

The following steps can be performed in any order.

1 Review the four CH-10-1 Chemistry P Review CH-1 0-1 Chemistry Recommendation Forms for Unit 2. Recommendation Forms.

Review CH-1 0 "Chemistry Goals".

2 Enter ON-126 "High Condensate P Recognize that condensate pump Conductivity" . discharge conductivity> 0.4 IJS/cm is a symptom for entry into ON-126.

! (Cue: If requested, report conductivities on CRS-2-12-132 are rising)

3 Determine that a plant shutdown per GP- P Recognize the chemistry change as a 3 "Normal Plant Shutdown" is required. severe conductivity intrusion (condenser tube leak) and ON-126 directs a plant shutdown using GP-3.

4 Determine that the 2A condenser P Determines that ON-126, step 2.4, directs waterbox needs to be removed from isolation of the source of the high service. conductivity. Using the CH-10-1 Chemistry Recommendation Forms the

examinee determines that conductivity is high on the discharge of the 2C condensate pump which is tied to the 2A waterbox.

PLOR259C Rev003

STEP NO STEP ACT STANDARD

5 Verify, immediately, by administrative P Recognize that Reactor Coolant System methods that Reactor Coolant System chloride concentration is > 0.2 ppm chloride concentration has not been> 0.2 (actual is 0.22 ppm) limit in TRM Table ppm for > 2 weeks in the last calendar 3.9-1, therefore, TRM 3.9.B applies.

year.

TRM 3.9.B applies. Verify that Reactor (Cue: if asked to assist with Coolant System chloride concentration administrative check of chloride has not been> 0.2 ppm for> 2 weeks in concentration, reply as the Chemistry the last calendar year.

Manager and report that chloride concentration has been < 0.2 ppm for the last calendar year.

6 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.

I I Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the determination of what immediate plant and/or regulatory actions, if any, exist, the evaluator will then terminate the exercise.

PLOR259C Rev003

TASK CONDITIONS/PREREQUISITES

1. Unit 2 has been at 1000/0 power for 160 days.

2. The Hydrogen Water Chemistry System is in service.

3. Chemistry has delivered four CH-10-1 Chemistry Recommendation Forms related to Unit 2 condensate conductivity and reactor water chloride concentration.

4. PMS conductivity values match values provided on the CH-10-1 forms.

5. All the samples have been verified.

INITIATING CUE The Shift Manager directs you to determine what immediate plant and/or Technical SpecificationlTRM/ODCM actions, if any, exist for the above conditions.

CH-I0, Rev. 16 Page 11 of 'I ATTACHMENT CH-I0-l ATTACHMENT CH-IO-l EXAMPLE ONLY CHEMISTRY RECOMMENDATION (CR)

CR #3659-13 FROM: CHEMISTRY TO: SHIFT SUPERVISOR

SUBJECT:

CHEMISTRY RECOMMENDATION SECTION A ** COMPLETED BY SHIFT CHEMIST **

DATE/TIME SYSTEM PARAMETER LIMITS VALUE FOUND To-da-y / Unit 2 2A Condensate Pump 0.4 0.065 Now Condensate Discharge Conductivity llS/cm i llS/cm IS THIS CR A FOLLOW-UP TO A VERBAL NOTIFICATION? YES ~

IF YES, DATE/TIME AND PERSON NOTIFIED. N/A DATE / TIME N/A PERSON NOTIFIED CORRECTIVE ACTION REQUIRED: Confirm, investigate, and determine corrective actions, if any.

SECTION B ** COMPLETED BY SHIFT OPERATIONS PERSONNEL **

THE FOLLOWING CORRECTIVE ACTION WAS TAKEN: - - - - - - - - - ' _...._

DATE TIME CORRECTIVE ACTION TAKEN:

SHIFT OPERATOR VERBALLY NOTIFY CHEMISTRY AFTER CORRECTIVE ACTION IS COMPLETED PERSON NOTIFIED: - - - - - - - - - - - - - DATE/TIME- - - - - - - - ' _ .... _

- - - - RETURN THIS SHEET TO CHEMISTRY *****

CHEMISTRY REVIEW:

DATE

CH-I0, Rev. 16 Page 11 of 17 ATTACHMENT CH-IO-l EXAMPLE ONLY CHEMISTRY RECOMMENDATION (CR)

CR #3660-13 FROM: CHEMISTRY TO: SHIFT SUPERVISOR

SUBJECT:

CHEMISTRY RECOMMENDATION

.. .. .. .. .. .. .. .. .. .. .. .. .. .. .. to .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. '"

SECTION A ** COMPLETED BY SHIFT CHEMIST **

DATE/TIME SYSTEM PARAMETER LIMITS VALUE FOUND To-da-y / Unit 2 2B Condensate Pump 0.4 0.065 Now Condensate Discharge Conductivity llS/cm llS/cm IS THIS CR A FOLLOW-UP TO A VERBAL NOTIFICATION? YES ~

IF YES, DATE/TIME AND PERSON NOTIFIED. N/A DATE / TIME N/A PERSON NOTIFIED CORRECTIVE ACTION REQUIRED: Confirm, investigate, and determine corrective actions, if any.

SECTION B ** COMPLETED BY SHIFT OPERATIONS PERSONNEL **

THE FOLLOWING CORRECTIVE ACTION WAS TAKEN:

DATE TIME CORRECTIVE ACTION TAKEN:

SHIFT OPERATOR VERBALLY NOTIFY CHEMISTRY AFTER CORRECTIVE ACTION IS COMPLETED PERSON NOTIFIED: ________________________DATE/TIME__.. __________________

- - - - RETURN THIS SHEET TO CHEMISTRY *****

CHEMISTRY REVIEW: - - - - -

DATE

CH-I0, Rev. 16 11 of EXAMPLE ONLY CHEMISTRY RECOMMENDATION (CR)

CR #3661-13 FROM: CHEMISTRY TO: SHIFT SUPERVISOR SUB,JECT: CHEMISTRY RECOMMENDATION SECTION A ** COMPLETED BY SHIFT CHEMIST **

DATE/TIME SYSTEM PARAMETER LIMITS VALUE FOUND To-cia-y / Unit 2 2C Condensate Pump 0.4 2.6 Now Condensate Discharge Conductivity llS/cm llS/cm IS THIS CR A FOLLOW-UP TO A VERBAL NOTIFICATION? YES ~

IF YES, DATE/TIME AND PERSON NOTIFIED. N/A DATE / TIME N/A PERSON NOTIFIED CORRECTIVE ACTION REQUIRED: Confirm, investigate, and determine corrective actions, if any.

SECTION B ** COMPLETED BY SHIFT OPERATIONS PERSONNEL **

THE FOLLOWING CORRECTIVE ACTION WAS TAKEN:

DATE TIME CORRECTIVE ACTION TAKEN:

SHIFT OPERATOR VERBALLY NOTIFY CHEMISTRY AFTER CORRECTIVE ACTION IS COMPLETED PERSON NOTIFIED: __________________~______ DATE/TIME____________________~

- - - - RETURN THIS SHEET TO CHEMISTRY *****

CHEMISTRY REVIEW: - - - - - - - - - -

DATE

CH-10, Rev. 16 Page 11 of "7 ATTACHMENT CH-I0-1 EXAMPLE ONLY CHEMISTRY RECOMMENDATION (CR)

CR #3662-13 FROM: CHEMISTRY TO: SHIFT SUPERVISOR

SUBJECT:

CHEMISTRY RECOMMENDATION SECTION A ** COMPLETED BY SHIFT CHEMIST **

I DATE/TIME SYSTEM PARAMETER LIMITS VALUE FOUND To-da-y /

Now Unit 2 Reactor Chlorides

-< 0.2 ppm 0.22 ppm Coolant Conductivity < 1.0 pS/em 0.97 pS/em IS THIS CR A FOLLOW-UP TO A VERBAL NOTIFICATION? YES ~

IF YES, DATE/TIME AND PERSON NOTIFIED. N/A DATE / TIME PERSON NOTIFIED CORRECTIVE ACTION REQUIRED: Confirm, investigate, and determine corrective actions, if any.

SECTION B ** COMPLETED BY SHIFT OPERATIONS PERSONNEL **

THE FOLLOWING CORRECTIVE ACTION WAS TAKEN:

DATE TIME CORRECTIVE ACTION TAKEN:

.. -~-

SHIFT OPERATOR VERBALLY NOTIFY CHEMISTRY AFTER CORRECTIVE ACTION IS COMPLETED PERSON NOTIFIED: DATE/TIME

- - - - RETURN THIS SHEET TO CHEMISTRY *****

CHEMISTRY REVIEW: _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

DATE

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET each Bottom Limerick Commo

~ JPM D QUALIFICATION MANUAL D OJT MODULE Licensed Operator Training PLOR-347CA Licensed Operator Requalification 001 J. A. Verbillis jav Evaluation of High CRD Temperature on Control Rod Scram Time (SRO)

APPROVALS:

Signature I Title Date Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: _ _ _-_ _ _"_ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE 10 NO. COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

SignaturelDate PLOR347CA Rev001

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Senior Reactor Operator TASK-JPM DESIGNATOR: 20110504021 PLOR-347CA KIA: G2.1.32 SRO: 4.0 TASK DESCRIPTION: Review AO 3.8 Attachment 1 for High CRD Temperature A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical . .IPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

PLOR347CA Rev001 Page 2 of6

8. TOOLS AND EQUIPMENT

1. Calculator

2. Unit 3 Tech Spec 3.1.3,3.1.4 and Bases

3. AT2 - In-progress AO 3.8, with data recorded - Required

4. AT3 - Core Map (NF-PB-721, At 7) - Optional- for classroom setting C. REFERENCES

1. AO 3.8 Rev 0, "Evaluation of High CRD Temperature on Control Rod Scram Time"

2. Tech Spec 3.1.3, 3.1.4 and Bases

3. Core Map, such as NF-PB-721 At 7 D. TASK STANDARD

1. Satisfactory task completion is indicated when Control Rod 18-55 is declared SLOW or INOPERABLE and AO 3.8 is complete.

2. Estimated time to complete: 20 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, complete the Shift Management review of the in-progress AO 3.8 for Control Rod 18-55. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Unit 3 is at 100% power.

2. Eight Control Rods (10-35,14-43,14-55,18-59,22-35,30-27,34-51,42-43) are currently classified as SLOW.

3. Control Rod 18-55 temperature is 405 of and cannot be lowered.

4. System Manager has provided the latest Scram Time data for CR 18-55:

Position 46 - 0.343 Sec Position 36 - 0.844 Sec Position 26 -1.396 Sec Position 06 - 2.599 Sec

5. AO 3.8 has been completed up through Step 4.7, including Attachment 1.

PLOR347CA Rev001 Page 3 of6

G. INITIATING CUE As the Control Room Supervisor, review Attachment 1 of AD 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time" for Unit 3 Control Rod 18-55 and complete AD 3.8.

Identify Technical Specification compliance issues and required actions, if any. (Candidate to document results on back of Cue Sheet) (Hand the candidate the in-progress copy of AD 3.8 with Attachment 1 complete through the Independent Verification.)

PLOR347CA Rev001

H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 REVIEW AO 3.8 up to and including step P AO 3.8, "Evaluation of High CRD 4.6. I Temperature on Control Rod Scram Time" is reviewed.

- - - NOTE ****

The Alternate Path portion of this JPM begins with the next step_

2 RECOGNIZE that Scram Time for Control P Scram time for position(s) 46, 36, and/or Rod 18-55 is unacceptable. 26 are recognized to be greater than

Tech Spec allowance .

(CUE: If informed, acknowledge as i appropriate.}

3 DECLARE Control Rod 18-55 "slow". P Control Rod 18-55 declared slow.

(CUE: If informed, acknowledge as appropriate. )

4 VERIFY Compliance with Technical P TS 3.1.3 and 3.1.4 reviewed.

Specifications 3.1.3 AND 3.1.4.

(Cue: N/A)

5 RECOGNIZE Non-Compliance with LCO P TS LCO 3.1.3 and/or LCO 3.1.4.b being 3.1.3 and/or 3.1.4.b. exceeded is recognized. (Control Rods 14-55, 18-59 are identified as SLOW in (CUE: If informed, acknowledge as the Initiating Cue; Control Rod 18-55 appropriate.)

results in THREE Control Rods occupying "adjacent locations".)

6 NOTIFY EDM and direct that Engineering P EDM is involved as required by IMMEDIATELY verify the accuracy of the procedure.

temperature corrected control rod scram time calculation.

(CUE: Inform candidate that Engineering concurs with all calculations and control rod speed data.)

- - NOTE ***

Either of the alternatives in step 7 are acceptable.

II PLOR347CA Rev001

STEP STEP ACT STANDARD NO

7 DETERMINE that Tech Spec 3.1.4 P Action Statement understood.

Condition A Required Actions will require Unit 3 to be placed in Mode 3 within 12 Hours.

- OR -OR DECLARE Control Rod 18-55 (OR 18-59 Tech Spec 3.1.3 ACTION C Required OR 14-55) INOPERABLE, and apply Actions are identified as an acceptable Tech Spec 3.1.3 Condition C Required and in fact preferred alternative. (One of Actions. the three adjacent rods must be declared INOPERABLE)

(CUE: If informed, acknowledge as appropriate. )

8 Verify an Issue Report is generated for P Issue Report generated or task to Control Rod 18-55. generate issue has been assigned.

(Cue: IR generated.)

9 Notify System Manager of status of P System Manager notified.

Control Rod 18-55 AND Tech Spec Required Shutdown.

(Cue: As System Manager, acknowledge report.)

10 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.

I Under "ACT' P - must perform S - must simulate I. TERMINATING CUE When Control Rod 18-55 is declared SLOW or INOPERABLE and AO 3.8 is complete, the evaluator will terminate the exercise.

PLOR347CA Rev001 Page 6 of6

TASK CONDITIONS/PREREQUISITES

1. Unit 3 is at 1000/0 power.

2. Eight Control Rods (10-35, 14-43, 14-55, 18-59, 22 35, 30-27, 34-51, 42-43) are currently classified as SLOW.

3. Control Rod 18-55 temperature is 405 of and cannot be lowered.

4. System Manager has provided the latest Scram Time data for CR 18-55:

Position 46 - 0.343 Sec Position 36 - 0.844 Sec Position 26 - 1.396 Sec Position 06 - 2.599 Sec

5. AO 3.8 "Evaluation of High CRD Temperature on Control Rod Scram Time" has been completed up through Step 4.7, including Attachment 1.

INITIATING CUE As the Control Room Supervisor, review Attachment 1 of AO 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time" for Unit 3 Control Rod 18-55 and complete AO 3.8. Identify Technical Specification compliance issues and required actions, if any.

(Document your results on the back of this cue sheet.)

NF-PB-721 Revision 2 Page 10 of 11 Attachment 7 - Full Core Control Rod Map PREDICTED VALUES POWERMWT STATION' UNIT _ _ _,_ _

POWER % PATTERN TITLE _ _ _ _,

FLOW MLB/HR (%) _ _ _ VALID FROM _ _ _ _THROUGH _ __

Maximum MFLCPR _ _ __ AT _ _ - _ __

Maximum MFLPD AT _ _ - ___ - _ _

Maximum MAPRAT _______ AT _ _ _ _ _ _ __

PREPARED BY_ __ APPROVED BY_ _ _ _ _ _ __

A = Actual Position * = POSITION 48 T = Target Position 59 IArYI A T 55 l';~~:Fh, "Q@:i, I I 51 ;~;li,i ,Lt~"j :\,t~;(? ':~@Ri I I I I 47 ';fQp:" 1~$ii!W 1FiilG;t~ ~QS2;i !l(".!'"

I I I I I 43 F~~'1'" '1'a'" ;'8Az," t:wm, 'tei','" a:a~,

I I I I I I 39 ";:'IIE~:i< :1 uJ:.11", i:;'#)\1",:';, "1~JI!i?i:' !1j:.!$i' i;l1ll~;::;:

L I I I I !'inj,,',',",

I 35 ;:"'701\1:" )H!lA1(' "fj1!ii(': ,';i)~A"r :iT8~i:

I I I I I I 31 'UYc: "',\ilt';', :'1lJA'," ':":'9A:"i' ""c",," ,tot:

I I I I I I 27 'i:l.C'1,' ;",'BA~' "'(.Ii;: :;\::'1#.0)' ;i$A'I,: ':ic~:

I I I I I I 23 ~1!::,' :j!1:Q~1: """",:j;)~:;: q,)!t).lIi'n ;::i$)$, " ','tUB't' ,

I I I I I I 19 ';1lef; ,jlB,i' '~: ,j:'~': '['.rEf' , ,',aar:

I I I I I I 1 _ _ _ _ _ __ ~l:iti:t,; :',t1OC": 'Ileil'i:'

I I I 3 ________________

02 06 1 0 1 4 18 22 26 30 34 38 42 46 50 54 58

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET Peach Bottom QUALIFICATION MANUAL OJT MODULE PLOR-273C Licensed Operator Requalification 000 C. N. Croasmun cnc f'r"rnnensatory Actions for an Inoperable Fire Door APPROVALS:

Sig nature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: ____-_ _ _--' _ _ __

NAME: ISSUE DATE:

Last First MJ.

EMPLOYEE 10#: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

SignaturelDate PLOR273C RevOOO

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 3410170302 / PLOR-273C KIA: G2.2.40 SRO: 4.7 TASK DESCRIPTION: Ability to determine actions required for an Inoperable Fire Door A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" ..IPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

PlOR273C RevOOO

B. TOOLS AND EQUIPMENT

1. A copy of ST-0-037-390-2 "Fire Door Electrical Supervisory Alarm System"

2. Drawing A-486 "Barrier Plan" Elev. 135'

3. Technical Requirements Manual section 3.14 C. REFERENCES

1. ST-0-037 -390-2 "Fire Door Electrical Supervisory Alarm System"

2. Drawing A-486 "Barrier Plan" Elev. 135'

3. Technical Requirements Manual section 3.14 D. TASK STANDARD

1. Satisfactory task completion is indicated when the Technical Requirements Manual compensatory measures have been identified.

2. Estimated time to complete: 15 minutes Non-Time Critical.

E. DIRECTIONS TO EXAMINEE When given the initiating cue, determine any actions required to be taken for Fire Door #217 Supervisory Alarm System failing to alarm.

F. TASK CONDITIONS/PREREQUISITES

1. Fire Door supervisory alarm testing is in progress in accordance with ST-0-037 -390-2 "Fire Door Electrical Supervisory Alarm System".

2. You have just been notified that Fire Door #217 has been fully open for eleven minutes, and has failed to alarm.

3. Previous fire surveillance testing has determined that all smoke detectors on Turbine Building 135' are operable.

G. INITIATING CUE As the Unit 2 Control Room Supervisor review ST-0-037 -390-2 "Fire Door Electrical Supervisory Alarm System" and identify any required action(s) for Fire Door #217. Document required action(s) on the cue sheet.

PLOR273C RevOOO Page 3 of 5

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain a copy of ST-0-037-390-2 "Fire P ST-0-037-390-2 "Fire Door Electrical Door Electrical Supervisory Alarm Supervisory Alarm System" obtained.

System".

(Cue: Provide the candidate with a copy of ST-0-037-390-2) 2 Determine Fire Door location. P Review ST-0-037-390-2 Data Sheet 1, and determine Fire Door 217 is located on TB2 elevation 135' in the 2A & 2C Battery Room.

3 Review ST-0-037-390-2 sections 4 and P Review ST-0-037-390-2 "Fire Door

5. Electrical Supervisory Alarm System" for Precautions, Limitations, General Instructions, and Acceptance Criteria.

4 Identify Fire Door #217 classification. P Review ST 037-390-2 section 4 and determine Fire Door #217 is a Safety Related door identified by an

on Data Sheet 1.

5 Review ST-0-037-390-2 Performance P Review ST-0-037-390-2 section 6 for Steps and Corrective actions. Test Requirements and Corrective Actions.

6 Identify alarm requirements for Fire Door P Determine Fire Door #217 is required to

217. alarm in less than or equal to 10 minutes, and is INOPERABLE.

7 Obtain a copy of the Unit 2 Technical P Obtain a copy of the Unit 2 Technical Requirements Manual. Requirements Manual and review section 3.14 Fire Protection Systems.

(Cue: Provide the candidate with a copy of the Unit 2 Technical Requirements Manual.)

8 Determine Unit 2 Technical P Review Technical Requirements Manual Requirements Manual required action. section 3.14.8 condition A and establish a Fire Watch Patrol within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once per hour there after for Unit 2 TB 135' 2A

& 2C Battery Room.

PLOR273C RevOOO

9 Inform the Evaluator of task completion. P The operator informs the Evaluator of task completion.

(Cue: The Control Room Supervisor acknowledges the report.)

10 As an evaluator ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the Technical Requirement Manual compensatory actions have been identified, and the evaluator has been informed, the evaluator will terminate the exercise.

PLOR273C RevOOO

TASK CONDITIONS/PREREQUISITES

1. Fire Door supervisory alarm testing is in progress in accordance with ST 0-037-390-2 "Fire Door Electrical Supervisory Alarm System".

2. You have just been notified that Fire Door #217 has been fully open for eleven minutes, and has failed to alarm.

3. Previous fire surveillance testing has determined that all smoke detectors on Turbine Building 135' are operable INITIATING CUE As the Unit 2 Control Room Supervisor review ST-0-037-390-2 "Fire Door Electrical Supervisory Alarm System" and identify any required action(s) for Fire Door #217. Document required action(s) on the cue sheet:

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET

~ JPM D QUALIFICATION MANUAL OJT MODULE

~-=~~----------~I LICENSED OPERATOR TRAINING PLOR-256C LICENSED OPERATOR REQUALI FICATION 002 M. J. Kelly Jav REVIEW AND APPROVE PRIMARY CONTAINMENT PURGENENT ISOLATION VALVE CUMULATIVE HOUR LOG APPROVALS:

Signature I Title Date Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: _ _---:'_ _-----',_ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE 10#: : COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date PLOR256C Rev002

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2270140201/ PLOR-256C KIA: G2.3.13 SRO: 3.8 TASK DESCRIPTION: Perform Primary Containment PurgeNent Isolation Valve Cumulative Log.

A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" ..'PM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph D.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph D.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

PLOR256C Rev002

B. TOOLS AND EQUIPMENT

1. Calculator

2. Copy of ST-O-007-560-2, "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log".

3. A calculation error made on Data Sheet 1 such that "Accumulated Total Time Since Beginning of Calendar Year" is greater than 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months , with the procedure completed to indicate total time is less than 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months (use Attachment 2 of this JPM for exact values).

C. REFERENCES

1. ST-O-007-560-2, Rev. 2, "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log".

D. TASK STANDARD

1. Satisfactory task completion is indicated when the Shift Management review has been completed, the calculation error on Data Sheet 1 identified, and the total accumulated time a purge/vent valve is open has been determined to be greater than 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months .

2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to review the Primary Containment PurgeNent Isolation Valve Cumulative Hour Log. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. The "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log" for Unit 2 (ST-O-007-560-2) has been completed.

2. The "Accumulated Total Time Since Beginning of Year" is greater than 80 hours9.259259e-4 days 0.0222 hours 1.322751e-4 weeks 3.044e-5 months . Shift Management has been notified as required by Step 6.1.6.

G. INITIATING CUE You are the Work Control Supervisor. Perform the Plant Staff review and approval of ST-O-007-560-2, "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log". Initial to annotate "Sat/Unsat" for each of the five entries on Data Sheet 1.

PLOR256C Rev002 Page 3 of 5

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Cue: Hand the Examinee a completed copy of 51-0-007-560-2," Primary Containment I

PurgeNent Isolation Valve Cumulative Hour Log" with Data Sheets 1 and 2 data filled in by hand from Attachment 2 of this JPM.

2 Review S1-0-007-560-2 for P Verifies all procedure steps, Data Sheet completeness. 1, and Data Sheet 2 have been completed satisfactorily.

3 Verify calculations. P Performs all calculations that were done on Data Sheet 1 to verify they are correct and properly recorded.

4 Recognize calculation errors. P Recognizes the following calculation errors on Data Sheet 1:

1. Second row of the "Flow Path Open Total Time" column should be 17 Hr, 4 Min versus 5 Hr, 4 Min.

2. Fourth row of the "Accumulated Total Time Since Beginning of Calendar Year" column total is incorrect...one additional hour should be added.

NOTE: the "critical" part of this step is to recognize the first error and the fact that the accumulated total time has exceeded 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months .

5

Determines the "Accumulated Total Time P Determines the "Accumulated Total Time Since Beginning of Year" is beyond the Since Beginning of Year" is 93 Hr, 22 Min Acceptance Criteria specified in Step 5.0. versus 80 Hr, 22 Min.

6 Notify Shift Management of unsatisfactory P Reports to Shift Manager and/or Control test results. Room Supervisor that the "Accumulated Total Time Since Beginning of Year" is

(Cue: Acknowledge report.) greater than 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months .

7 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task

Conditions/Prerequisites) AND I procedures.

PLOR256C Rev002 Page 4 of 5

Under "ACT' P - must perform S - must simulate I. TERMINATING CUE When the review of ST-O-007-560-2 has been completed, the calculation error on Data Sheet 1 identified, and the total accumulated time a purge/vent valve is open has been determined to be greater than 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months , the evaluator will terminate the exercise.

PLOR256C Rev002 Page 5 of 5

TASK CONDITIONS/PREREQUISITES

1. The "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log" for Unit 2 (ST-O-007-560-2) has been completed.

2. The "Accumulated Total Time Since Beginning of Year" is greater than 80 hours9.259259e-4 days 0.0222 hours 1.322751e-4 weeks 3.044e-5 months .

Shift Management has been notified as required by Step 6.1.6.

INITIATING CUE You are the Work Control Supervisor.

Complete the Plant Staff review and approval of ST-O-007-560-2, "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log".

Initial to annotate "Sat/Unsat" for each of the five entries on Data Sheet 1.

DATA SHEET 1 6" AND 18" FLOW PATH TOTAL HOUR LOG Any 6" or 18" ALL 6' or 18' Flow Flow Path Accumulated Total Time Accumulated Total Time Flow Path Open OR Paths Closed OR Open Total Since Beginning of Since Beginning of Req'd Conditions Required Conditions Time Calendar Year (Note 1) Calendar Year < 90 hrs Exist for Timing No Longer Exists with Valves Open (Hours &

Minutes)

Initial TIME DATE TIME DATE Total Fwd: 61 Hr, 28 Min .fu!!. Unsat 0131 12/19108 0411 12119108 2 Hr,40 Min 64 Hr, 8 Min R-I:J 0428 12/19/08 2132 12119108 5 Hr, 4 Min 69 Hr, 12 Min R-I:J 2147 12/19/08 2319 12119/08 1Hr, 32 Min 70 Hr, 44 Min R~I:J 0916 12123108 1706 12123108 7 Hr, 50 Min 77 Hr, 34 Min R~I:J 1154 12124108 1442 12124108 2 Hr, 48 Min 80Hr, 22 Min R~I:J R-I:J R-I:J R-I:J R-I:J R~I:J R-I:J R-I:J R-I:J R-I:J NOTE 1: IF "Accumulated Total T Since Beginn of Year" is er than or 1 to 80 hrs, THEN NOTIFY SMgt.

DATA SHEET 2 DAY / SHIFT DATE FLOW PATHS USED tial (See below) Sat Unsat 1 2 3 4 5 6 7 MON D 12118108 N/A N/A N/A N/A N/A N/A N/A N N/A N/A ".j -,j ".j ".j N/A TUE D 12119108 N/A N/A N/A --J N/A N/A

".j ".j WED N

D 12120108 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N " N/A N/A N/A N/A N/A N/A Nil.>;

THUR D 12/21/08 N/A N/A N/A N/A N/A N/A N/A N " N/A N/A N/A N/A N/A N/A N/A FRI D 12122/08 N/A N/A N/A N/A N/A N/A N/p" N " N/A N/A N/A N/A N/A N/A N/p.

-,j SAT D N

12123108 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A SUN D N

12124108 N/A

".j N/A N/A N/A N/A N/A

".j N/A N/A N/A N/A AO-2-07B-25l9 and A.O-2-07B-2520 OPEN in a Drywell N2 Purge Flowpath AO-2-07B-2519 and AO-2-07B-25~:lB OPEN in a Torus N2 Purge t'lowpath

3. AO-2-CnB-2505 and A.O-2-07B-2520 OPEN in a Drywell Purge Supply F'lowpath

4. AO-2-07B-2521A and AO-2-07B-2521B OPEN in a Torus Purge Supply Flowpath

5. AO-2-07B-2506 and AO-2-07B-2507 OPEN in a Drywell Exhaust FlO';>lpath

6. AO-2-07B-2S11 and AO-2-07B-2512 OPEN in a Torus Exhaust Flowpath

7. Abnormal Flowpath.

==

Description:==

D Day Shift - 6:30a - 6:30p N Night Shi - 6:30p - 6:30a

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET Peach Bottom

~ JPM D QUALIFICATION MANUAL D OJT MODULE LICENSED OPERATOR TRAINING PLOR-230C LICENSED OPERATOR REQUALIFICATION 003 J. T. Hanley jth EAL CLASSIFICATION WITH STATE AND LOCAL NOTIFICATIONS (FS1, wind from 0 degrees, airborne release in progress)

APPROVALS:

Signature / Title Date Signature I Title Date Signature I Title Date Signature' Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: ____'_ _ _--c _ _ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE 1.0. NO. . COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date PLOR230C Rev003

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE I POSITION TITLE: Senior Reactor Operator I TASK-JPM DESIGNATOR: 2007540502 I PLOR-230C 2.4.40 I KIA SRO: 4.5 I TASK DESCRIPTION: Emergency Director A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

PLOR230C Rev003

B. TOOLS AND EQUIPMENT None C. REFERENCES

1. EP-AA-112-100, Rev. 011, "Control Room Operations"

2. EP-AA-111, Rev. 018, "Emergency Classification and Protective Action Recommendations"

3. EP-MA-114-100, Rev. 018, "Mid-Atlantic State/Local Notifications"

4. EP-MA-114-1 00-F-01, Rev L, "State/Local Notification Form

5. EP-AA-112-100-F-01, Rev. P, "Shift Emergency Director Checklist"

6. EP-AA-1007, Table PBAPS 3-1, Rev. 26, "Emergency Action Level (EAL) Matrix

7. EP-AA-114-F-02, Rev. A, "BWR Release in Progress Determination Guidance"

8. EP-AA-125-1002, Rev 008, "ERO Performance - Performance Indicators Guidance" D. TASK STANDARD

1. Performance Location: Simulator

2. Satisfactory task completion is indicated when EP-MA-114-1 00-F-01, "State/Local Event Notification Form" has been completed accurately.

(NOTE: The criteria for accurate Event Notification form completion was derived from EP-AA-125-1002, Rev. 008, "ERO Performance - Performance Indicators Guidance".)

3. Estimated time to complete: TIME CRITICAL

Event Classification: 15 minutes

State/Local Notification Form: 13 minutes E. DIRECTIONS TO EXAMINEE When given the initiating cue, make the Emergency Classification and complete the State/Local Notifications, if required. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. A plant event occurred 15 minutes ago that resulted in damage to the reactor fuel on Unit 2.

2. A Main Steam Line (MSL) HI-HI radiation signal generated a Group I isolation signal.

PLOR230C Rev003 Page 3 of 7

3. Six of the eight MSIVs closed.

4. The "A" MSL inboard and outboard MSIVs failed to close.

5. A full reactor scram occurred; all rods are in.

6. RPV level and pressure are normal, being maintained with HPCI, RCIC, and SRVs.

7. 2 VENT EXH STACK RAD MONITOR HI-HI B (218 C-4) annunciator is in alarm.

8. Vent Stack release rate has been 4.5 E+6 uCi/sec for the last 15 minutes as read on RI 2979A and B.

9. A sample of the Reactor coolant has an activity of 265 uCi/gm 1-131 dose equivalent.

10. A steam leak has just been identified in the Turbine Building.

11. Wind Speed: 3 mph, Wind Direction: 000 G. INITIATING CUE As Emergency Director, make the EAL Classification, if required, and complete EP-MA-114 100-F-01, State/Local Notification Form.

PLOR230C Rev003 Page 4 of 7

H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO

- - NOTE ****

Record the time using the clock above the Full Core Display. Time =

1 Obtain a copy of EP-AA-112-100-F-01 P Copies of EP-AA-112-100-F-01 and EP and EP-AA-1007. AA-1007 are obtained.

2 Determine that the Vent Stack release P Radiological Effluent EAL RA1 is rate is greater than the ALERT level reviewed. Vent Stack release rate is threshold but less than the SITE AREA determined to be above the ALERT level EMERGENCY level threshold. (>3.83 E+6 uCi/sec) but less than the SITE AREA EMERGENCY level <<3.36 E+7 uCi/sec).

3 Determine that the reactor coolant activity P Abnormal Rad Level EAL RU3 and level is greater than the UNUSUAL Fission Product Barrier Matrix is EVENT level but less than the threshold reviewed. Reactor Coolant activity is value for a LOSS of FUEL CLAD determined to be above the UNUSUAL BARRIER. EVENT level (> 4.0 uCi/gm).

4 Determine that the failure of the "A" MSL P The failure of the "A" MSL to isolate to isolate exceeds the Fission Product exceeds the Fission Product Barrier Barrier Matrix thresholds resulting in a Matrix thresholds resulting in a LOSS of LOSS of both the REACTOR COOLANT both the REACTOR COOLANT SYSTEM SYSTEM BARRIER and the PRIMARY BARRIER and the PRIMARY CONTAINMENT BARRIER. CONTAINMENT BARRIER.

5 Using the Fission Product Barrier Matrix, P A SAE (FS1) is declared based on the identify that these losses constitute a two losses identified in the Fission SITE AREA EMERGENCY (SAE) Product Barrier Matrix.

declaration (FS 1) 6 Announce the event classification to the S SAE is announced.

facility staff.

- - NOTE ****

Record the time using the clock above the Full Core Display. Time =

- - NOTE ***

Inform the examinee that the Public Address Announcement and the ERO Notification required by EP AA-112-1 00-F-01, Shift Emergency Director Checklist, are NOT required for this JPM.

- - NOTE ***

The following steps are associated with completion of EP-MA-114-100-F-01, "State/Local Event Notification Form."

7 Check the call status. P "This is a drill" line is checked in Block #1.

8 Check the affected station. P "Peach Bottom" is checked in Block #2.

PLOR230C Rev003 Page 5 of 7

STEP STEP ACT STANDARD NO

9 Check the event classification. P "SITE AREA EMERGENCY" classification is checked in Block #3a.

10 Check the affected unit. P Unit "Two" is checked in Block #3b.

11 Enter the time and date of the P Declaration time (in 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months clock declaration. nomenclature) and today's date are entered in Block #3c. The declaration time should match the time the examiner entered in the note before JPM step 1.

12 Check the applicable change in P "Initial Declaration" is checked in Block classification status. #3d.

13 Enter the EAL number declared ANDIOR P EAL# "FS1" is annotated in Block #4a provide a brief non-technical description AND a simplified explanation for the of event. event classification is provided in Block

4b. Acronyms, abbreviations or other terms that would not be recognized by state and local response agencies are avoided. The Offsite EAL Reference Manual may be referred to, if necessary.

14 Check the non-routine radiological P "AIRBORNE radiological release in-release status. progress" is checked (Block #5b). EP AA-114-F-01, "Release in Progress Determination Guidance" may be referenced.

15 Enter the wind direction "degrees from." P "0" is entered as the wind direction degrees from in Block #6a.

(Cue: Wind direction is from 0 degrees.)

16 Enter the wind speed. P Wind speed is entered as "3" miles per hour in Block #6b.

(Cue: Wind speed is 3 mph.)

17 Check the utility Protective Action P 7a, NOT APPLICABLE is checked.

Recommendation.

18 eck the appropriate conclusion. P "This is a drill" line is checked in Block #8.

19 Approve the event notification form. P The event notification form is signed in the form's header area by the Emergency Director.

- - NOTE ***

WHEN the examinee completes the Event Notification form, THEN record the time using the clock above the Full Core Display. Time =

Determine if the elapsed time since the classification exceeds 13 minutes.

PLOR230C Rev003

STEP STEP ACT STANDARD NO 20 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When EP-MA-114-1 OO-F-O 1, "State/Local Event Notification Form" has been completed, the evaluator will terminate the exercise.

PLOR230C Rev003 Page 7 of 7

TASK CONDITIONS/PREREQUISITES

1. A plant event occurred 15 minutes ago that resulted in damage to the reactor fuel on Unit 2.

2. A Main Steam Line (MSL) HI-HI radiation signal generated a Group I isolation signal.

3. Six of the eight MSIVs closed.

4. The "A" MSL inboard and outboard MSIVs failed to close.

5. A full reactor scram occurred; all rods are in.

6. RPV level and pressure are normal, being maintained with HPCI, RCIC, and SRVs.

7. 2 VENT EXH STACK RAD MONITOR HI-HI B (218 C-4) annunciator is in alarm.

8. Vent Stack release rate has been 4.5 E+6 uCi/sec for the last 15 minutes as read on RI-2979A and B.

9. A sample of the Reactor coolant has an activity of 265 uCi/gm 1-131 dose equivalent.

10. A steam leak has just been identified in the Turbine Building.

11. Wind Speed: 3 mph, Wind Direction: 000 INITIATING CUE As Emergency Director, make the EAL Classification, if required, and complete EP-MA-114-1 00-F-01, State/Local Notification Form.

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET Limerick Common JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR REQUALIFICATION 000 J. A. Verbillis jav HPSW Injection into the Fuel Pool (ALTERNATE PATH: HPSW Pump Overcurrent, Use Other Pump)

APPROVALS:

Signature I Title Date Signature I Title Date i APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: ____'____"_ __

NAME: ISSUE DATE:

Last First M,1.

EMPLOYEE 1.0. NO. COMPLETION DATE:

COMMENTS:

i Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date l

Page 1 of 9

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2770390401/ PLOR-376CA KIA: 233000A2.02 RO: 3.1 SRO: 3.3 TASK DESCRIPTION: HPSW Injection into the Fuel Pool A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

Page 2 of9

B. TOOLS AND EQUIPMENT

1. Keys for MO-174 and MO-176 C. REFERENCES Procedure AO 32.3-2, Rev. 2, HPSW Injection into the Fuel Pool D. TASK STANDARD

1. Performance Location: Simulator

2. Satisfactory task completion is indicated when HPSW is injecting into the Fuel Pool via RHR using "B" HPSW pumps.

3. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to inject HPSW into the Fuel Pool using the 2B HPSW pumps using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Unit 2 Fuel Pool level is lowering, and use of AO 32.3-2, "HPSW Injection into the Fuel Pool" has been directed by Shift Management.

2. All of the 4 KV busses are receiving power from the off-site startup source.

3. Unit 2 is in Mode 3.

4. 2B, D HPSW pumps are available.

5. RHR to FPC 16" Spool Piece is installed.

6. Access is available to:

Fuel Pool Service Water Booster Pump Area, Elev. 165', Reactor Bldg.

North Isolation Valve Room, Elev. 135', Reactor Bldg.

MCC E324-R-B, Elev. 135', Reactor Bldg.

7. Shift Manager has authorized delaying installation of Equipment Status Tags as permitted by Precaution 3.1 of the referenced procedure.

8. Unit 2 Reactor Operator has authorized use of B loop of HPSW for injection into the Fuel Pool.

Page 30f9

G. INITIATING CUE The Control Room Supervisor directs you to inject HPSW into the Fuel Pool using the "8" Loop of HPSW per AD 32.3-2, "HPSW Injection into the Fuel Pool", starting at Step 4.1.

Page 4 of9

H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 Verify 2BP035 "B RHR Pump" shutdown. P B RHR pump 2BP035 green light verified ON at panel 20C003 2 Verify 2DP035 "D RHR Pump" shutdown. P D RHR pump 2DP035 green light verified ON at panel 20C003 3 Verify 2BP042 "B HPSW Pump" P HPSW pump 2BP042 green light verified shutdown. ON at panel 20C003-02.

4 Verify 2DP042 "D HPSW Pump" P HPSW pump 2DP042 green light verified shutdown. ON at panel 20C003-02.

! 5 Verify MO-2-10-89B, 2B HPSW HX Outlet P MO-2-10-89B, green light verified ON at va Ive closed. pane120C003.

6 Verify MO-2-10-S90, 20 HPSW HX Outlet P MO-2-10-S9D, green light verified ON at valve closed. pane120C003.

7 Verify MO-2-1 0-039B, "Torus Header P MO-2-10-039B, green light verified ON at Valve" closed. panel 20C003.

S Verify MO-2-10-025B, "LPCllnjection P MO-2-10-025B, green light verified ON at Valve" closed. pane120C003.

9 Verify MO-2-10-026B, "Containment Spray P MO-2-10-026B, green light verified ON at Valve" closed. panel 20C003.

- - NOTE ***

Procedure requires MO-013B(D) be "verified" closed - since the normal position is OPEN, the candidate is expected to use the definition of the word "verified" as direction to manipulate the valve. A short discussion of this with supervision would be expected, and the Evaluator should role playas required without cuing the candidate.

10 CLOSE MO-2-10-013B, "B RHR Suction P Key is obtained from SSV key box and Valve". inserted into the MO-2-10-13B keylock switch. Key lock switch is taken to the CLOSEO position.

11 Verify MO-2-10-013B, "B RHR Suction P MO-2-10-013B, green light verified ON at Valve" closed. panel 20C003.

Page 50f9

Li STEP ACT STANDARD Verify MO-2-10-015B, "B RHR Suction P MO-2-10-015B, green light verified ON at Valve" closed. panel 20C003.

13 CLOSE MO-2-10-013D, 110 RHR Suction P Key is obtained from SSV key box and Valve". inserted into the MO-2 -1 0-13D keylock switch. Key lock switch is taken to the CLOSED position.

14 Verify MO-2-10-013D, "D RHR Suction P MO-2-10-013D, green light verified ON at Valve" closed. pane120C003.

15 Verify MO-2-10-015D, "D RHR Suction P MO-2-10-015D, green light verified ON at Valve" closed. panel20COO3.

16 Verify MO-2-32-2344 (10-186) IIHPSW P MO-2-32-2344 (10-186), green light Loop Cross Tie" closed. verified ON at panel 20COO3-03.

- - NOTE ***

Simulator Operator action is required for the following step.

17 Direct an Operator to Close or Verify P Operator dispatched to manipulate valve Closed HV-2-10-70B, RHR Pressurizing as directed, candidate does not proceed Line Block Valve To RHR Loop B" until report of valve status is received.

(Cue: HV-2-10-70B is CLOSED)

18 Direct an Operator to Unlock and Open P Operator dispatched to manipulate valve HV-2-10-180, "RHR Discharge to Fuel as directed, candidate does not proceed Pool Block Valve" until report of valve status is received.

(Cue: HV-2-10-180 is OPEN)

19 Direct an Equipment Operator to throttle P Operator dispatched to manipulate valve open throttle open EITHER as directed, candidate does not proceed HV-2-19-24457A OR HV-2-19-24457B, until report of valve status is received.

"RHR to Fuel Storage Pool Diffuser Block Valve" (Cue: HV-2-19-24457A is THROTTLED OPEN)

Page 6 of9

- - NOTE ***

Simulator Operator action is required for the following step.

20 Direct an Equipment Operator to CLOSE P Operator dispatched to manipulate E324-R-B (3863), "Emerg Intertie Valve breaker as directed, candidate does not MO-2-10-176" proceed until report of breaker status is (Cue: E324-R-B (3863) is CLOSED) received.

21 Verify position indication for MO-2-1 0-176, P MO-2-10-176, green light verified ON at "HPSW to RHR Emergency Outer Cross- panel 20C003-03 Tie" is ON at PaneI20C003-03.

22 Open MO-2-10-174, "HPSWI RHR Inner P Key is obtained from SSV keybox, Cross Tie" valve. inserted into MO-2-10-174, key lock switch and placed in the OPEN position at panel 20C003-03.

23 Verify MO-2-10-174, "HPSW/RHR Inner P MO-2-10-174, red light verified ON at Cross Tie" valve open. panel 20C003-03.

24 Open MO-2-10-176, "HPSW/RHR Outer P Key is obtained from SSV keybox, Cross Tie" valve. inserted into MO-2-10-176, keylock switch and placed in the OPEN position at panel 20C003-03.

25 Verify MO-2-10-176, "HPSW/RHR Outer P MO-2-10-176, red light verified ON at Cross Tie" valve open. panel 20C003-03.

26 Notify Shift Management that the "B" P Notification made.

HPSW Loop Pre-injection lineup is complete.

27 Perform GP-15 evacuation of Reactor S GP-15 evacuation requirement recognized Bldg. and discussed with Evaluator.

- NOTE**

Alternate Path starts with next step.

- NOTE**

Whichever HPSW pump is initially selected for start will exhibit Overcurrent indications.

Candidate is expected to respond by tripping the pump. IF candidate fails to take this action, the pump will trip automatically after 60 seconds. Automatic trip will require Simulator Operator action to remove trip function from other HPSW pump.

Page 7 of9

STEP STEP ACT STANOARO NO 28 Start the "28" or "20" HPSW pump. P "28" or "20" HPSW pump control switch is momentarily placed in the START position (Cue: Inform candidate that HPSW at paneI20C003-04.

System Flow on FI-2-10-1328 is 4000 gpm) 29 Identify HPSW pump overcurrent P Recognizes ammeter indicates condition. overcurrent condition, acknowledges 225 E-5 or 226 E-3 pump overcurrent alarm.

30 Secure the running HPSW pump. P "28" or "20" HPSW pump control switch is momentarily placed in the STOP position at panel 20C003-04.

31 Start the "28" or "20" HPSW pump. P "28" or "20" HPSW pump control switch is momentarily placed in the START position at panel 20C003-04.

32 Verify proper start of the running HPSW P HPSW pump red light is ON, pump motor pump. amps are .....70 on ammeter 10A-A28(0).

(Cue: Inform candidate that HPSW System Flow on FI-2-10-1328 is 4000 gpm) 33 Verify fuel pool level is riSing by requesting S Candidate discusses need to monitor Fuel observation of fuel pool level or indirectly Pool level for effect of injection either by by monitoring Fuel Floor and/or Fuel Pool direct observation or by indirect Rad levels. observation using Rad levels as described in AO 32.3-2 Step 4.3.15. The candidate (Cue: IF EO is dispatched to check Fuel may discuss requirement to secure pump Pool level, report that Fuel Pool level is to control Fuel Pool level as described in rising) Step 4.3.16.

34 Inform the Control Room Supervisor of P Task completion reported.

task completion.

35 As an evaluator ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) ANO procedures.

Page 8 of 9

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When either the "28" or "2D" HPSW pump is injecting into the fuel pool, the Control Room Supervisor should be informed. The candidate should make effort to ascertain effect of HPSW injection per procedure guidance. The evaluator will then terminate the exercise.

Page 9 of 9

TASK CONDITIONS/PREREQUISITES

1. Unit 2 Fuel Pool level is lowering, and use of AO 32.3-2, "HPSW Injection into the Fuel Pool" has been directed by Shift Management.

2. All of the 4 KV busses are receiving power from the off site startup source.

3. Unit 2 is in Mode 3.

4. 2B, D HPSW pumps are available.

5. RHR to FPC 16" Spool Piece is installed.

6. Access is available to:

Fuel Pool Service Water Booster Pump Area, Elev. 165', Reactor Bldg .

North Isolation Valve Room, Elev. 135', Reactor Bldg.

MCC E324-R-B, Elev. 135', Reactor Bldg.

7. Shift Management has authorized delaying installation of Equipment Status Tags as permitted by Precaution 3.1 of the referenced procedure.

8. Unit 2 Reactor Operator has authorized use of B loop of HPSW for injection into the Fuel Pool.

INITIATING CUE The Control Room Supervisor directs you to inject HPSW into the Fuel Pool using the "B" Loop of HPSW per AO 32.3-2, "HPSW Injection into the Fuel Pool",

starting at Step 4.1.

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET Peach Bottom Common D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING LICENSED OPERATOR REQUALIFICATION 000

~: ***:1 M. J. Kelly mjk RAISE HPCI FLOW (ALTERNATE PATH - SUCTION VALVES FAIL TO AUTO SWAP ON LOW CST LEVEL)

APPROVALS:

Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:

EFFECTIVE DATE: _ _------',_ _ _,_ __

NAME: ISSUE DATE:

Last First M.I.

EMPLOYEE NO. COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2060250101/ PLOR-333CA KIA: 206000A2.09 URO: 3.5 SRO: 3.7 TASK DESCRIPTION: Transfer of HPCI Suction From CST To Torus A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical ..IPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

Page 2 of 5

B. TOOLS AND EQUIPMENT None C. REFERENCES

1. Alarm Response Card 221 C-3, Rev. 4, Condensate Storage Tank Level Low-Low

2. Procedure SO 23.7.8-2, Rev. 7, "Transfer of HPCI Pump Suction from CST to Torus" (R)

D. TASK STANDARD

1. Satisfactory task completion is indicated when HPCI flow has been raised to 5000 gpm and pump suction is manually transferred from the CST to the Torus (Torus suction valves open and CST suction valve closed) without adverse effects on RPV injection.

2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to raise HPCI flowrate to 5000 gpm.

will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. HPCI is injecting into the RPV at 4000 gpm in response to a low RPV level transient.

2. RCIC is isolated.

3. Torus Cooling is in service per RRC 10.1-2, "RHR System Torus Cooling During a Plant Event."

G. INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to raise HPCI flowrate to 5000 gpm.

H. PERFORMANCE CHECKLIST STEP I NO STEP ACT STANDARD 1 : Raise HPCI Flow Rate to 5000 gpm. P :The HPCI Flow Controller knob is adjusted

in the clockwise direction to raise the flow rate setting from 4000 gpm to 5000 gpm.

2 IHPCI Flow is verified to rise toward 5000 I P FI-2-23-108 is monitored to verify that the gpm. actual flow rate rises to 5000 gpm.

i NOTE Approximately 15 seconds after flow has been raised to 4950 gpm, Annunciator 221 C-3 "CONDENSATE STOR TANK LEVEL LOW - LOW" will be received initiating the next part of the JPM.

3 I Recognize the Condensate Storage Tank P : Recognize by reporting annunciator 221 Low Level Condition alarm. : C-3 is alarming indicating a Low CST Level condition.

4 Obtain a copy of Alarm Response Card P I Candidate references ARC 221 C-3, 221 C-3. CONDENSATE STOR TANK LEVEL LOW-LOW.

5 Verify the Low CST Level Condition. P Candidate verifies that CST Level is low by referencing LR-2217 on 20C007A or LI-2217 OR LI-8453 on 20C004. (The candidate may also send an EO to verify level on LI-2210.)

6 Recognize that HPCI failed to P Candidate will recognize by reporting that automatically swap suction paths on low the HPCI suction path failed to CST level. automatically swap. (A RCIC suction

. swap is not required due to RCIC being

isolated.)

7 Obtain a copy of procedure SO 23.7.B-2 P A copy of procedure SO 23.7.B-2, OR "Transfer of HPCI Pump Suction from CST to Torus", is obtained. Steps 4.6 Implement auto actions of ARC 221 C-3.

through 4.9, OR The auto actions of ARC 221 C-3 should be referenced for transient conditions .

...... ~--

8 Open MO-2-23-057 HPCI Torus Suction P MO-2-23-057 control switch is valve. momentarily placed in the OPEN position then released at panel 20C004B.

I STEP

NO STEP ACT STANDARD

9 Open MO-2-23-058, HPCI Torus Suction P MO-2-23-058 control switch is valve. , momentarily placed in the OPEN position then released at pane120COO4B.

r 10 Verify MO-2-23-057 and MO-2-23-058, I P MO-2-23-057 and MO-2-23-058 red lights

,HPCI Torus Suction valves are open. are verified ON, and green lights OFF at I

pane120C004B.

i 11 I Verify MO-2-23~017 Cond Tank Suction P Recognize that MO-2-23-017 failed to

valve automatically closes when close as indicated by the green light MO-2-23-057 and MO-2-23-058 are full verified OFF and red light verified ON at open. ! panel 20C004B.

12 I Close MO-2-23-017, Cond Tank Suction P IMO-2-23-017 control switch is

'valve. i momentarily placed in the CLOSE position then released at panel 20C004B.

13 Verify MO-2-23-017, Cond Tank Suction P MO-2-23-017 green light is verified ON, valve is closed. *and red light OFF at panel 20C004B.

14 Check Level Switches responsible for the P Direct that LS-2-23-74 and LS-2-23-75 be automatic swap. checked for proper operation due to the failed auto transfer.

I!

I 15 Inform Control Room Supervisor of task P Task completion reported.

completion.

16 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material i provided to the examinee (Task Conditions/Prerequisites) AND rocedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the HPCI suction has been transferred to the Torus, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

TASK CONDITIONS/PREREQUISITES

1. HPCI is injecting into the RPV at 4000 gpm in response to a low RPV level transient.

2. RCIC is isolated.

3. Torus Cooling is in service per RRC 10.1-2, "RHR System Torus Cooling During a Plant Event."

INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to raise the HPCI flowrate to 5000 gpm.

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET ch Bottom Limeric Comm TYPE: ~ JPM D QUALIFICATION MANUAL D OJT MODULE PROGRAM: Licensed Operator Training COURSE: Licensed Operator Requalification M. J. Kelly

! TITtE: Reopen The Main Steam Isolation Valves After a GP I Isolation APPROVALS:

Signature I Title Date Signature I Title Date APPROVED FOR USE:

EFFECTIVE DATE: _ _ _-_ _ _ _ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE 10#: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date Page 1

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-..IPM DESIGNATOR: 2000800501/ PLOR-083C KIA: 239001A4.01 RO: 4.2 SRO: 4.0 TASK DESCRIPTION: Reopen the Main Steam Isolation Valves after a GP I Isolation A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. ..IPM Performance

a. "Control Room" ,JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

Page 2 of 6

B. TOOLS AND EQUIPMENT None C. REFERENCES Procedure T-221-2, Rev. 10, "Main Steam Isolation Valve Bypass" D. TASK STANDARD

1. Satisfactory task completion is indicated when Inboard MSIVs are open.

2. Estimated time to complete: 10 minutes Non-Time Critical DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to reopen the MSIVs using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Use of this procedure has been directed by the TRIP procedures.

2. Main Condenser is available.

3. RPV level is known.

4. There is no indication of gross fuel failure.

5. There is no indication of a Main Steam Line break.

6. All T-221 Tool Packages have been obtained.

7. Inboard and Outboard MSIVs are closed.

8. Steps 4.1 thru 4.5 of T-221-2, "Main Steam Isolation Valve Bypass" are complete.

G. INITIATING CUE The Control Room Supervisor directs you to perform T-221-2, "Main Steam Isolation Valve Bypass" steps 4.6 through 4.12 in order to reopen the MSIVs.

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain a copy of procedure T-221-2. A copy of procedure T-221-2 is obtained.

2 Open AO-2-02-086A "A" Outboard MSIV. P AO-2-02-086A control switch is placed in the "AUTO/OPEN" position at panel 20C003-01.

3 Verify AO-2-02-086A "A" Outboard MSIV P AO-2-02-086A red light is verified ON at is open. panel 20C003-01.

4 Open AO-2-02-0868 "8" Outboard MSIV. P AO-2-02-0868 control switch is placed in the "AUTO/OPEN" position at panel 20C003-01.

5 Verify AO-2-02-0868 "8" Outboard MSIV P AO-2-02-0868 red light is verified ON at is open. paneI20C003-01.

6 Open AO-2-02-086C "C" Outboard MSIV. P AO-2-02-086C control switch is placed in the "AUTO/OPEN" position at panel 20C003-01.

7 Verify AO-2-02-086C "C" Outboard MSIV P AO-2-02-086C red light is verified ON at is open. panel 20C003-01.

8 Open AO-2-02-086D "D" Outboard MSIV. P AO-2-02-086D control switch is placed in the "AUTO/OPEN" position at panel 20C003-01.

9 Verify AO-2-02-086D "D" Outboard MSIV P AO-2-02-086D red light is verified ON at is open. panel 20C003-01.

10 Open MO-2-02-077, Outboard Main P MO-2-02-077 control switch is Steam Drain valve. momentarily placed in the "OPEN" position at panel 20C003-03.

11 Verify MO-2-02-077, Outboard Main P MO-2-02-077 red light is verified ON at Steam Drain valve open. panel 20C003-03.

12 Open MO-2-02-074, Inboard Main Steam P MO-2-02-074 control switch is Drain valve. momentarily placed in the "OPEN" position at panel 20C003-03.

STEP NO STEP ACT STANDARD i

13 Verify MO-2-02-074 Inboard Main Steam P MO-2-02-074 red light is verified ON at Drain valve is open. panel 20C003-03.

14 Verify closed MO-2-02-079, Orifice Bypass P MO-2-02-079 green light is verified ON at to Main Cndr valve. panel 20C003-03.

15 Open MO-2-02-078, Downstream Drain P MO-2-02-078 control switch is I

valve. momentarily placed in the "OPEN" position at panel 20C003-03.

16 Verify MO-2-02-078 Downstream Drain P MO-2-02-078 red light is verified ON at valve is open. panel 20C003-03.

17 Observe pressure differential across the P Pressure differential across the Inboard Inboard MSIVs. MSIVs is determined using PI-2-06-090A(B)(C) at panel 20C005A, Determine the difference between Reactor and "Steam Line" PR-2865 at panel I pressure on PI-2-06-090A(B)(C) and 20C008A.

"Steam Line" pressure on PR-2865 on pane120C008A.

18 Verify differential pressure across the P Differential pressure across the inboard inboard MSIVs is less than 150 psid. MSIVs is verified less than 150 psig on PI-2-06-090A(B}(C} at panel 20C005A, and "Steam Line" PR-2865 at panel 20C008A.

19 Open AO-2-02-080A "A" Inboard MSIV. P AO-2-02-080A control switch is placed in the "AUTO/OPEN" position at panel 20C003-01.

20 Verify AO-2-02-080A "A" Inboard MSIV is P AO-2-02-080A red light is verified ON at open. panel 20C003-01.

21 Open AO-2-02-080B "B" Inboard MSIV. P AO-2-02-080B control switch is placed in the "AUTO/OPEN" position at panel 20C003-01.

22 Verify AO-2-02-080B "B" Inboard MSIV is P AO-2-02-080B red light is verified ON at open. paneI20C003-01.

23 Open AO-2-02-080C "C" Inboard MSIV. P AO-2-02-080C control switch is placed in the "AUTO/OPEN" position at panel 20COO3-01.

24 Verify AO-2-02-080C "C" Inboard MSIV is P AO-2-02-080C red light is verified ON at open. panel 20COO3-01.

II 6

STEP NO STEP ACT STANDARD

25 Open AO-2-02-080D "0" Inboard MSIV. P AO-2-02-080D control switch is placed in the "AUTO/OPEN" position at panel 20COO3-01.

26 Verify AO-2-02-080D "0" Inboard MSIV is P AO-2-02-080D red light is verified ON at open. panel 20COO3-01.

27 Inform Control Room Supervisor of task P Task completion reported. I completion.

28 As an evaluator ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task I Conditions/Prerequisites) AND

,I procedures .

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the MSIVs have been reopened, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

TASK CONDITIONS/PREREQUISITES

1. Use of this procedure has been directed by the TRIP procedures.

2. Main Condenser is available.

3. RPV level is known.

4. There is no indication of gross fuel failure.

5. There is no indication of a Main Steam Line break.

6. All T-221 Tool Packages have been obtained.

7. Inboard and Outboard MSIVs are closed.

8. Steps 4.1 thru 4.5 of T -221-2, "Main Steam Isolation Valve Bypass" are complete.

INITIATING CUE The Control Room Supervisor directs you to perform T-221-2, "Main Steam Isolation Valve Bypass" steps 4.6 through 4.12 in order to reopen the MSIVs.

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET Peach Botto Limerick Comm T¥PE: JPM D QUALIFICATION MANUAL I OJT MODULE

. PROGRAM! LICENSED OPERATOR TRAINING COURSE; LICENSED OPERATOR REQUALIFICATION 000 T¥PIST: jav PERFORM CORE SPRAY B PUMP CAPACITY TEST FOR 1ST (Alternate Path Minimum Flow Valve Fails to Open)

APPROVALS:

Signature / Tille Date Signature / Title Date APPROVED FOR USE:

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE 10#: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

SignaturelDate

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-"IPM DESIGNATOR: 2090140101/ PLOR-335CA KIA: 209001A4.04 URO: 2.9 SRO: 2.9 TASK DESCRIPTION: Ability to manually operate and/or monitor Core Spray minimal flow valves in the control room A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. "IPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

B. TOOLS AND EQUIPMENT

1. None C. REFERENCES

1. ST-0-014-212-2, Rev. 2, "Core Spray B Pump Capacity Test for 1ST" D. TASK STANDARD

1. Satisfactory task completion is indicated when it is recognized that the Core Spray B Pump has no minimum flow protection, the pump is secured, and Core Spray B loop is returned to a normal standby lineup, as specified in the performance steps of ST-0-014 212-2, Section 6.0.

2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to perform Core Spray 2B pump capacity test for 1ST using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. The plant is operating at 100% power.

2. An Equipment Operator is standing by in the 2B and 2D Core Spray Pump Rooms.

3. Communications are available between the Control Room, 2B and 2D Core Spray Pump Rooms, Band D Core Spray Pump Triangle Room, and Cable Spreading Room.

4. Core Spray pump 2B oil level is between the minimum and maximum lines on the sightglass.

5. Core Spray pump 2B static pump suction pressure is 6 psig.

6. All data recording will be performed (simulated) by a second operator.

7. 2B Core Spray pump flow (Computer point H056) is displayed on XI-80187E on the C03-04 panel and on TRIP Table left-side computer screen.

Page 3 of 8

G. INITIATING CUE The Control Room Supervisor directs you to perform Core Spray 28 Pump Capacity Test for 1ST in accordance with ST-O-014-212-2 (provided).

Provide examinee a copy of ST-O-014-212-2 with the following items completed:

Section 1 of the cover page

Procedure section 2.0, "Test Equipment"

Procedure section 3.0, "Prerequisites" Page 4 of 8

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Complete step 6.1.1 of ST-O-014-212-2 P Places "N/A" at step 6.1.1 of ST-O-014 as "Not Applicable" 212-2.

2 Verify oil level in the 2B Core Spray pump P Places initials in "Sat" column of step is between the operating range minimum 6.1.2 of ST-O-014-212-2.

and maximum lines on sightglass.

3 Record static pump suction pressure from P Documents "6 psig" and places initials in PI-2-14-036B "2B Core Spray Pump "Sat" column of step 6.1.3 of ST-O-014 Suction Pressure". 212-2.

4 CLOSE MO-2-14-011 B "Core Spray P MO-2-14-011 B control switch is Outboard Disch". momentarily placed in "CLOSE" at Panel 20COO3.

5 VERIFY CLOSED MO-2-14-011 B "Core P Verifies that MO-2-14-011 B green light is Spray Outboard Disch". ON; red light is OFF at Panel 20COO3.

- - - NOTE: ****

If this JPM is being performed in parallel with another ..IPM, direct candidate NOT to make the plant page announcement prior to starting 28 Core Spray pump.

6 START 2BP037 "Core Spray B Pump". P "Starting 2B Core Spray pump" is announced on plant page prior to starting Core Spray pump 2B.

2B Core Spray pump control switch is momentarily placed in the "START" position at Panel 20COO3.

7 VERI FY Core Spray 2B Pump STARTS P 2B Core Spray pump green light is and is RUNNING by observing motor verified OFF, red light is verified ON.

current on 14A-M'1 B and discharge Pump motor amps on ammeter 14A-M 1B pressure on PI-2-14-048B "Core Spray and discharge pressure on PI-2-14-048B Disch P". are verified rising at Panel 20COO3.

8 VERIFY MO-2-14-0058 "Core Spray 8 P MO-2-14-0058 green light is verified Min Flow" automatically OPENS. OFF; red light is verified ON at Panel 20COO3.

Page 5 of 8

STEP NO STEP ACT STANDARD 9 VERI FY 2DP037 "Core Spray D Pump" is P Directs Equipment Operator to verify NOT rotating. Core Spray D Pump is NOT rotating.

(Cue: When requested, report that the Core Spray D Pump is NOT rotating and its discharge check valve indicates closed.)

10 OPEN MO-2-14-026B "Core Spray Full P MO-2-14-026B control switch is Flow Test". momentarily placed in "OPEN" at Panel 20C003.

11 VERIFYOPEN MO-2-14-026B "Core P MO-2-14-026B green light is verilied Spray Full Flow Test". OFF; red light is verified ON at Panel 20C003.

12 VERIFY MO-2-14-00SB "Core Spray B P MO-2-14-00SB green light is verified ON; Min Flow" automatically CLOSES. red light is verified OFF at Panel 20C003.

- - - NOTE: ****

Time-compress by telling the examinee Core Spray B Pump has been running for 5 minutes.

Remind examinee that a second operator has successfully recorded all full flow test data on Data Sheet 1.

Page 6 of 8

- - - NOTE: ****

The Alternate Path portion of this JPM begins with the next step_

13 THROTTLE MO-2-14-0268 "Core Spray P MO-2-14-0268 control switch is Full Flow Test" to obtain Rated Flow of momentarily placed in "CLOSE" at Panel 3125 to 3175 gpm as read on computer 20C003. Red pushbutton is depressed to point H056. stop valve stroke. Attempt made to operate valve control switch and red pushbutton to achieve 3125 to 3175 gpm as read on PMS computer point H056.

Recognizes that the MO-2-14-0268 has ramped close unexpectedly and that the green closed light is ON and that the red open light is verified OFF at Panel 20C003.

Report to the CRS that the MO-2-14 0268 full flow test valve for the 28 Core Spray Pump has failed to properly operate 14 VERIFY MO-2-14-0058 "Core Spray 8 P Recognizes that the MO-2-14-0058 green Min Flow" automatically OPENS. light is ON; red light is OFF at Panel 20C003. The Min. Flow Valve has not automatically opened.

Report to the CRS that the minimum flow valve for the 28 Core Spray Pump has failed to properly operate.

- - NOTE: ***

IF after 2 minutes, a flowpath is not established AND the Core Spray pump has not been secured, THEN the Simulator Operator will TRIP the Core Spray pump, resulting in inability to successfully complete the critical step and the candidate will FAIL this JPM.

15 SHUTDOWN 28P037 "Core Spray 8 P 28 Core Spray pump control switch is Pump". momentarily placed in the "STOP" position at Pane120C003.

OR 28 Core Spray pump green light is Re-open MO-2-14-0268 "Core Spray Full verified ON, red light is verified OFF.

Flow Test". Pump motor amps on ammeter 14A-M1 8 and discharge pressure on PI-2-14-0488 are verified at zero at Panel 20C003.

OR MO-2-14-0268 control switch is momentarily placed in "OPEN" at Panel 20C003. Verifies valve is full open.

16 Inform Control Room Supervisor of task P Control Room Supervisor notified MO-2 completion. 14-0268 malfunction and test being aborted.

17 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When it is recognized that the Core Spray 8 Pump has no minimum flow protection and the pump is secured, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

TASK CONDITIONS/PREREQUISITES

1. The plant is operating at 100% power.

2. An Equipment Operator is standing by in the 28 and 2D Core Spray Pump Rooms.

3. Communications are available between the Control Room, 28 and 2D Core Spray Pump Rooms, 8 and D Core Spray Pump Triangle Room, and Cable Spreading Room.

4. Core Spray pump 28 oil level is between the minimum and maximum lines on the sightglass.

5. Core Spray pump 28 static pump suction pressure is 6 psig.

6. All data recording will be performed (simulated) by a second operator.

7. 28 Core Spray pump flow (Computer point H056) is displayed on XI-S01S7E on the C03-04 panel and on XI-S0190E at the TRIP Table left-side computer screen.

INITIATING CUE The Control Room Supervisor directs you to perform Core Spray 28 pump capacity test for 1ST in accordance with ST-0-014-212-2 (provided).

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET I.!:::==='lll Li merick I QUALIFICATION MANUAL D O..IT MODULE

_Sys_e LICENSED OPERATOR REQUALIFICATION

""""::$,>1 PERFORM A GROUP I PCIS ISOLATION RESET (GP-8A)

APPROVALS:

Signature I Title Date Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: _ _----.:1_ _-----..:1_ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE ID#: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

VI~nature/Date

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2000490501 / PLOR-024C KIA: 223002A4.03 URO: 3.6 SRO: 3.5 TASK DESCRIPTION: Perform a Group I PCIS Isolation Reset GP-8A)

A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" ..IPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this ..IPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this "IPM, though listed in the task standard, is not to be given to the examinee.

B. TOOLS AND EQUIPMENT Hand the Examinee a copy of C.O.L. GP-8.A with "As Found Position" column initials already filled in.

C. REFERENCES

1. Procedure GP-8.A, Rev. 10, "PCIS Isolation - Group I"

2. C.O.L. GP-8.A, Rev. 8, "Group I Isolation" D. TASK STANDARD

1. Satisfactory task completion is indicated when the PCIS Group I Isolation is reset.

2. Estimated time to complete: 8 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to reset the PCIS Group I isolation using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. The plant had been at 100% power.

2. A PCIS Group I isolation has occurred and has been verified to be a result of Main Steam tunnel high temperature.

3. The cause of the PCIS Group I isolation has been corrected, and the isolation signal is clear.

4. The plant is in a safe, stable shutdown condition.

5. CAV (Crack Arrest Verification) System is not in operation.

6. GP-8.A, "PCIS Isolation - Group I" steps 3.1 and 3.2 have been completed.

7. There is no indication of fuel damage.

8. There is no evidence of a steam leak.

G. INITIATING CUE The Control Room Supervisor directs you to reset the PCIS Group I isolation logic per steps 4.1 through 4.4 of GP-8.A, "PCIS Isolation - Group I".

Page 3 of 8

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain copies of procedures GP-SA P Copies of procedures GP-SA and and COL GP-SA. COL GP-SA are obtained.

- NOTE**

Provide examinee with the marked up COL GP-8A.

2 Place switch to "CLOSE" for P AO-2-02-0S0A control switch placed AO-2-02-080A. in the "CLOSE" position at panel 20C003-01.

3 Initial the AO-2-02-0S0A box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-0S0A initialed on COL GP-SA. GP-SA.

4 Place switch to "CLOSE" for P AO-2-02-0S0B control switch placed AO-2-02-0S0B. in the "CLOSE" position at panel 20C003-01.

5 Initial the AO-2-02-0S0B box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-0S0B initialed on COL GP-8A. GP-SA.

6 Place switch to "CLOSE" for P AO-2-02-0S0C control switch placed AO-2-02-0S0C. in the "CLOSE" position at panel 20COO3-01.

7 Initial the AO-2-02-0S0C box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-0S0C initialed on COL GP-SA. GP-SA.

S Place switch to "CLOSE" for P AO-2-02-0S0D control switch placed AO-2-02-0S0D. in the "CLOSE" position at panel 20C003-01.

9 Initial the AO-2-02-0S0D box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-0S0D initialed on COL*

GP-SA. GP-SA.

10 Place switch to "CLOSE" for P AO-2-02-0S6A control switch placed AO-2-02-0S6A. in the "CLOSE" position at panel 20COO3-01.

11 Initial the AO-2-02-086A box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-086A initialed on COL GP-8A. GP-8A.

12 Place switch to "CLOSE" for P AO-2-02-086B control switch placed AO-2-02-086B. in the "CLOSE" position at panel 20C003-01.

13 Initial the AO-2-02-086B box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-0S6B initialed on COL GP-SA. GP-SA.

14 Place switch to "CLOSE" for P AO-2-02-0S6C control switch placed AO-2-02-086C. in the "CLOSE" position at panel 20C003-01.

15 Initial the AO-2-02-0S6C box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-0S6C initialed on COL GP-SA. GP-SA.

16 Place switch to "CLOSE" for P AO-2-02-0S6D control switch placed AO-2-02-0S6D. in the "CLOSE" position at panel 20C003-01.

17 Initial the AO-2-02-0S6D box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-0S6D initialed on COL GP-SA. GP-SA.

1S Verify switch in "CLOSE" for P AO-2-02-039 control switch verified AO-2-02-039. in the "CLOSE" position at panel 20C004A.

19 N/A or initial the AO-2-02-039 box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-2-02-039 N/A'd or initialed on GP-8A. COL GP-SA.

20 Verify switch in "CLOSE" for P AO-2-02-040 control switch verified AO-2-02-040. in the "CLOSE" position at panel 20C004A.

21 N/A or initial the AO-2-02-040 box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-2-02-040 N/A'd or initialed on GP-8A. COL GP-SA.

22 Verify switch in "CLOSE" for P AO-2-02-316 control switch verified I AO-2-02-316. in the "CLOSE" position at panel 20C003-03.

23 N/A or initial the AO-2-02-316 box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-2-02-316 N/A'd or initialed on GP-8A. COL GP-8A.

24 Verify switch in "CLOSE" for P AO-2-02-317 control switch verified AO-2-02-317. in the "CLOSE" position at panel 20COO3-04.

25 N/A or initial the AO-2-02-317 box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-2-02-317 N/A'd or initialed on GP-8A. COL GP-8A.

26 Verify MO-2-02-074 is CLOSED. P MO-2-02-074 green light verified ON at panel 20C003-03.

27 N/A or initial the MO-2-02-074 box in P "CHECKED BY" column for the "CHECKED BY" column on COL MO-2-02-074 N/A'd or initialed on GP-8A. COL GP-8A.

28 Verify MO-2-02-077 is CLOSED. P MO-2-02-077 green light verified ON at panel 20COO3-04.

29 N/A or initial the MO-2-02-077 box in P "CHECKED BY" column for the "CHECKED BY" column on COL MO-2-02-077 N/A'd or initialed on GP-8A. COL GP-8A.

30 Verify switch in "CLOSE" for P AO-8098A control switch verified in AO-8098A. the "CLOSE" position at panel 20COO3-04.

31 N/A or initial the AO-8098A box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL 8098A N/A'd or initialed on COL GP-8A. GP-8A.

32 Verify switch in "CLOSE" for P AO-8098C control switch verified in AO-8098C. the "CLOSE" position at panel 20COO3-04.

33 N/A or initial the AO-8098C box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-8098C N/A'd or initialed on COL GP-8A. GP-8A.

34 Verify switch in "CLOSE" for P AO-8099A control switch verified in AO-8099A. the "CLOSE" position at panel 20COO3-04.

35 N/A or initial the AO-8099A box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-8099A N/A'd or initialed on COL GP-8A. GP-8A.

36 Verify switch in "CLOSE" for P AO-8099C control switch verified in AO-8099C. the "CLOSE" position at panel 20C003-04.

37 N/A or initial the AO-8099C box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL 8099C N/A'd or initialed on COL GP-8A. GP-8A.

38 Verify switch in "CLOSE" for P AO-8098B control switch verified in AO-8098B the "CLOSE" position at panel 20C003-02.

39 N/A or initial the AO-8098B box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL 8098B N/A'd or initialed on COL GP-8A. GP-8A.

40 Verify switch in "CLOSE" for P AO-8098D control switch verified in AO-8098D. the "CLOSE" position at panel 20C003-02.

41 N/A or initial the AO-8098D box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL 8098D N/A'd or initialed on COL GP-8A. GP-8A.

42 Verify switch in "CLOSE" for P AO-8099B control switch verified in AO-8099B. the "CLOSE" position at panel 20C003-02.

43 N/A or initial the AO-8099B box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL 8099B N/A'd or initialed on COL GP-8A. GP-8A.

44 Verify switch in "CLOSE" for P AO-8099D control switch verified in AO-8099D. the "CLOSE" position at panel 20C003-02.

45 N/A or initial the AO-8099D box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL 8099D N/A'd or initialed on COL GP-8A. GP-8A.

- NOTE**

The C.O.L. steps for AO*2256 "Condenser Offgas to Mechanical Vacuum Pump (MVP)"

and the MVP are not required to be performed and can be marked as N/A.

46 Place the Inboard PCIS Reset P The Inboard PCIS Reset Switch is Switch, 16A-S32, in the "GRP I" momentarily placed in the "GRP I" position. position at panel 20C005A.

47 Place the Outboard PCIS Reset P The Outboard PCIS Reset Switch is Switch, 16A-S33, in the "GRP I" momentarily placed in the "GRP I" position. position at panel 20C005A.

48 Verify "CHANNEL A and B GROUP I P The "CHANNEL A and B GROUP I ISOLATION RELAYS NOT RESET" ISOLATION RELAYS NOT RESET" annunciators clear. annunciators 211 H-1 and 211 J-1 are verified not lit.

49 Inform Control Room Supervisor of P Task completion reported.

task completion.

50 As an evaluator, ensure that you P Positive control established.

have positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND i procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the PCIS Group I isolation is reset, the Control Room Supervisor should be informed.

The evaluator will then terminate the exercise.

Page 8 of 8

TASK CONDITIONS/PREREQUISITES

1. The plant had been at 100% power.

2. A PCIS Group I isolation has occurred and has been verified to be a result of Main Steam tunnel high temperature.

3. The cause of the PCIS Group I isolation has been corrected, and the isolation signal is clear.

4. The plant is in a safe, stable shutdown condition.

5. CAV (Crack Arrest Verification) System is not in operation.

6. GP-S.A, "PCIS Isolation - Group I" steps 3.1 and 3.2 have been completed.

7. There is no indication of fuel damage.

S. There is no evidence of a steam leak.

INITIATING CUE The Control Room Supervisor directs you to reset the PCIS Group I isolation logic per steps 4.1 through 4.4 of GP-S.A, "PCIS Isolation - Group I".

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET JPM D QUALIFICATION MANUAL D OJT MODULF II CR_Sys_f LICENSED OPERATOR REQUALIFICATION 000 jav EXCITING THE MAIN GENERATOR APPROVALS:

Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: _ _ _.,_ _----',_ __

NAME: ISSUE DATE:

Last First M.1.

Employee 10 NO. COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date

EXELON NUCLEAR PEACH BODOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 23701101011 PLOR-031C KIA: 262001A4.04 RO: 3.6 SRO: 3.7 TASK DESCRIPTION: EXCITING THE MAIN GENERATOR A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

Page 2 of 5

B, TOOLS AND EQUIPMENT None C. REFERENCES Procedure SO SO.1.A-2 Rev, 16, "Main Generator Synchronizing and Loading" (R)

D, TASK STANDARD 1, Performance Location: Simulator

2. Satisfactory task completion is indicated when the Main Generator is excited, generator terminal voltage is adjusted to 22 KV, and the automatic voltage regulator is in service.

3, Estimated time to complete: 10 minutes (A.S) Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to excite the Main Generator using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task, F, TASK CONDITIONS/PREREQUISITES 1, Plant startup in progress with reactor power at approximately 18%.

2, All SO SO.1.A-2, "Main Generator Synchronizing and Loading" prerequisites are met.

3. The Power System Director has been notified.

G. INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to excite the Main Generator and place the automatic voltage regulator in service in accordance with steps 4.1 through 4.10 of SO SO.1.A-2, "Main Generator Synchronizing and Loading,"

H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 Obtain a copy of SO 50.1.A-2. P A copy of SO 50.1.A-2 is obtained.

2 Verify "GENERATOR INSULATION OVER P "GENERATOR INSULATION OVER HEATING" annunciator is clear. HEATING" annunciator is verified clear on alarm panel 206 L-2.

3 Verify the "Load Selector" pushbutton is P Load Selector REMOTE/AUTO selected to REMOTE/AUTO. pushbutton is depressed and the light is verified ON at panel 20C008A.

4 Verify "ReglTransfer" switch 43-0601 in P Regulator Transfer switch 43-0601 is MANUAL. verified in the MANUAL position at panel 20C009.

5 Verify the Manual DC Volt Regulator P Manual DC Voltage Regulator 70-0601 70-0601 set at minimum. green and amber lights are verified ON at Panel 20C009.

6 Direct an Equipment Operator to P Equipment Operator is directed to periodically monitor machine gas pressure periodically monitor machine gas pressure on PI-4356. on PI-4356.

7 Close the "Alt Exc Fld Bkr" 41-0601. P Alterrex Exciter Field Breaker control switch 41-0601 is momentarily placed in the CLOSE position at pane120C009.

8 Verify Field Volts, Amps and Generator P FIELD AMPS and VOLTS and Volts rise and red deexcitation backup GENERATOR VOLTS are verified to RISE light lit. and DEEXCITATION backup red light is verified ON and green light OFF at panel 20C009.

9 Adjust GENERATOR output voltage to P Manual DC Voltage Regulator 70-0601 is obtain 21.5 - 22.5 KV using MAN. DC adjusted to obtain a GENERATOR output VOLT REGULATOR 70-0601. voltage between 20.9 and 23.1 KVat panel 20C009.

10 Verify GENERATOR output voltage is P GENERATOR output voltage is verified between 21.5 - 22.5 KV. between 21.5 and 22.5 KV on GEN VOLTMETER at panel 20C009.

11 Adjust the "Auto Voltage Reg P Auto Voltage Reg Rheostat 90P is Rheostat"(90P) to obtain a "Reg Man/Auto adjusted to obtain a reading within 2 volts Deviation" voltage of 0 VDC. of 0 on the Reg Man/Auto Deviation meter at panel 20C009.

Page 4 of 5

STEP STEP ACT STANDARD NO 12 Verify "Reg Man/Auto Deviation voltage is P Reg Man/Auto Deviation voltage is verified CDVDC. to be CD VDC on the Reg Man/Auto Deviation voltmeter at pane120C009.

13 Verify "GEN VOLT REG AUTO TO MAN P liGEN VOL T REG AUTO TO MAN UNBALANCED" annunciator is clear. UNBALANCED" annunciator is verified clear on alarm panel 220 C-3.

14 Place the "Regffransfer" switch 43-0601 P Regffransfer switch 43-0601 is placed in in "AUTO". the AUTO position at panel 20C009.

15 Verify the "Regffransfer" lights indicate P Regffransfer red light is verified ON and auto regulation. green light verified OFF at panel 20C009.

16 Verify generator speed control. P Candidate operates the Load Selector pushbuttons to Raise freq by 0.5 hz, then Lower freq by 0.5 hz (below initial value) then raise freq to initial value.

17 Verify generator voltage control. P Candidate operates the Auto Voltage Reg Rheostat to Raise voltage by 0.5 KV, then Lower voltage by 0.5 KV (below initial value) then raise voltage to initial value.

18 Inform the Control Room Supervisor of P Task completion reported.

task completion.

19 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the Main Generator exciter field breaker is closed, the automatic voltage regulator is in service, and frequency and voltage control is verified, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

TASK CONDITIONSIPREREQUISITES

1. Plant startup in progress with reactor power approximately 18%.

2. All SO 50.1.A-2, "Main Generator Synchronization and Loading" prerequisites are met.

3. The Power System Director has been notified.

INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to excite the Main Generator and place the automatic voltage regulator in service in accordance with steps 4.1 through 4.10 of SO 50.1.A-2, "Main Generator Synchronization and Loading."

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET 01 TYPE: ~ JPM ()Ut,LIFICATION MANUAL D OJT MODULE flROGRAM: Licensed Operator Training Licensed Operator Requalification REV#:: 000 AUTHOR: M. J. Kelly TYPIST: Jav T1TLE: Scram Reset APPROVALS:

APPROVED FOR USE:

EFFECTIVE DATE: _ _----'1_ _ _.1_ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE 10 #: COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2120090101/ PLOR-004C KIA: 212000A4.14 RO: 3.8 SRO: 3.8 TASK DESCRIPTION: SCRAM RESET A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. ...IPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

Page 2 of 7

B. TOOLS AND EQUIPMENT Key for Scram Discharge Volume High Level Bypass Switch.

C. REFERENCES GP-11.E, Rev. 21, "Reactor Protection System - Scram and ARI Reset" D. TASK STANDARD

1. Satisfactory task completion is indicated when the Reactor Protection System is reset and the Scram Discharge Volume Vent and Drain valves are open.

2. Estimated time to complete: 19 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to reset a scram and begin draining the Scram Discharge Volume using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. A Main Turbine trip has caused a reactor scram.

2. Plant conditions have stabilized with RPV level at 23 inches.

3. RPV pressure is being maintained below 1050 psig with Bypass Valves.

4. T-100, "Scram" is complete.

5. All scram valves are open. All SDV Vent and Drain valves are shut.

6. A CRD pump is operating.

7. Both RPS buses are energized.

8. The Reactor Mode switch is in "SHUTDOWN".

9. ARI was NOT initiated.

10. No fuel damage is suspected.

G. INITIATING CUE The Control Room Supervisor directs you to reset the scram in accordance with GP-11.E, "Reactor Protection System - Scram and ARI Reset" and begin draining the Scram Discharge Volume.

Page 3 of 7

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain a copy of GP-11.E, "Reactor P A copy of GP-11.E, "Reactor Protection Protection System - Scram and ARI System - Scram and ARI Reset" is Reset". obtained.

- - - NOTE: ****

Due to initial conditions, the examinee will begin at procedure step 3.6 2 Verify scram initiating signal clear or P "TURBINE STOP VLV. CLOSURE AND bypassed CONTROL VLV. FAST CLOSURE SCRAM BYPASS" annunciator is verified lit on alarm panel 210 A-2.

3 Place Scram Discharge Volume High P Key is obtained from CRS keybox, Water Level Bypass Keylock Switch to inserted into the Scram Discharge Volume "BYPASS", High Water Level Bypass Keylock Switch 5A-Sa and placed in the "BYPASS" position at panel 20C005A.

4 Acknowledge the IISCRAM DISCHARGE P The annunciator "ACKNOWLEDGE" VOLUME HI WATER LEVEL SCRAM pushbutton is depressed on panel BYPASS" annunciator. 20C005A.

5 Prior to resetting a full scram, notify P Contacts Rad. Protection personnel via Radiation Protection. radio, phone, or plant page.

(Cue: Evaluator responds as Rad.

Protection management and acknowledges notification.

6 Place Scram Reset switch in Group 1 and P Scram Reset switch 5A-S9 is taken to the 4 position then Group 2 and 3 position. "GROUP 1 & 4", and then "GROUP 2 & 3" positions at panel 20C005A.

7 Verify the four scram group white lights P All scram group white lights verified LIT on are lit on both the RPS cabinets. panels 20C015 and 20C017.

STEP NO STEP ACT STANDARD 8 Verify: P "A CHANNEL REACTOR AUTO SCRAM" "A CHANNEL AUTO SCRAM" and "B CHANNEL REACTOR AUTO SCRAM" "B CHANNEL AUTO SCRAM" and "A CHANNEL REACTOR MANUAL "A CHANNEL REACTOR MANUAL SCRAM" and SCRAM" "B CHANNEL REACTOR MANUAL "B CHANNEL REACTOR MANUAL SCRAM" SCRAM" annunciators are clear. annunciators are verified clear on alarm panels 211 B-1, 211 C-1, 211 0-1 and 211 E-1.

9 Monitor Scram Air header pressure. P Scram air header pressure is verified to be approximately 70 psig on PI-2-3-312 on pane120C124.

10 Verify "SCRAM VALVE PILOT AIR P "SCRAM VALVE PILOT AIR HEADER HEADER PRESS HI-LOW" annunciator is PRESS HI-LOW" annunciator is verified clear. clear on alarm panel 211 0-2.

11 Verify blue scram lights are off. P All blue scram lights are verified OFF on the Full Core Display.

- NOTE **

Steps 12 and 13 will take 20-30 minutes to clear.

Evaluator may time compress by providing indicated cues to candidates.

12 Verify "ACCUMULATOR TROUBLE" lights P All "ACCUMULATOR TROUBLE" lights are clear. are verified clear on the Full Core Display.

(Cue: All of the "ACCUMULATOR TROUBLE" lights are clear on the Full Core Display.)

13 Verify "CRD ACCUMULATOR LO PRESS P "CRD ACCUMULATOR LO PRESS HI HI LEVEL" annunciator is clear. LEVEL" annunciator is verified clear on alarm panel 211 E-2.

(Cue: Annunciator 211 E-2 is not lit.)

- NOTE **

Step 14 will take approximately 5 minutes to complete.

Evaluator may time compress by providing indicated cue to candidates.

14 Verify CRD System Cooling Water flow is P CRD System Cooling Water flow is 55 - 65 gpm. verified to be 55 - 65 gpm on FI-2-03-306 on panel 20C005A.

(Cue: CRD Cooling Water flow as read on FI-2-03-306 is 60 gpm.)

15 Place the Rod Drift Alarm Reset switch to P Rod Drift Alarm Reset switch 3A-S7 is the "Reset" position. momentarily placed to the "RESET" position and then released at panel 20C005A.

16 Verify the rod drift alarm lights are clear. P All of the rod drift alarm lights are verified clear on the Full Core Display.

17 Verify "ROD DRIFT" annunciator is clear. P "ROD DRIFT" annunciator is verified clear on alarm panel 211 D-4.

18 Place SDV Inboard Vent and Drain Valves P The SDV Inboard Vent and Drain Valve Switch, 5A-S14A, in "OPEN". control switch 5A-S 14A is momentarily placed in the "OPEN" position and then released at panel 20C005A.

19 Verify the SDV Inboard Vent and Drain P SDV Inboard Vent and Drain Valves red Valves indicate open. lights are verified ON, green lights are OFF at panel 20C005A.

20 Place SDV Outboard Vent and Drain P The SDV Outboard Vent and Drain Valve Valves Switch, 5A-S14B, in "OPEN". control switch 5A-S14B is momentarily placed in the "OPEN" position and then released at panel 20C005A.

21 Verify the SDV Outboard Vent and Drain P SDV Outboard Vent and Drain Valves red Valves indicate open. lights are verified ON, green lights are OFF at panel 20C005A.

22 Inform Control Room Supervisor of task P T ask completion reported.

completion.

(Cue: Control Room Supervisor acknowledges report.)

23 As an evaluator ensure you have positive P Positive control established.

control of all exam material provided to the examinee (Task Conditions I Prerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the scram is reset and the Scram Discharge Volume Vents and Drains are open, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

TASK CONDITIONS/PREREQUISITES

1. A Main Turbine trip has caused a reactor scram.

2. Plant conditions have stabilized with RPV level at 23 inches.

3. RPV pressure is being maintained below 1050 psig with Bypass Valves.

4. T -100, "Scram" is complete.

5. All scram valves are open. All SDV Vent and Drain valves are shut.

6. A CRD pump is operating.

7. Both RPS buses are energized.

8. The Reactor Mode switch is in "SHUTDOWN".

9. ARI was NOT initiated.

10. No fuel damage is suspected.

INITIATING CUE The Control Room Supervisor directs you to reset the scram in accordance with GP-11.E, "Reactor Protection System - Scram and ARI Reset" and begin draining the Scram Discharge Volume.

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET TYPE:

~ JPM D QUALIFICATION MANUAL D OJT MODULE PROGRAM: LICENSED OPERATOR TRAINING CODE#: CR_Sys_h COURSE: LICENSED OPERATOR REQUALIFICATION REV#:: 000 AUTHOR: J. E. McClintock TYPIST: jav TITLE: VERIFY ISOLATION OF DRYWELL CHILLED WATER AND RBCCW (ALTERNATE PATH - RBCCW IS SUPPLYING DRYWELL CHILLED WATER LOADS)

APPROVALS:

Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: I I NAME: ISSUE DATE:

Last First M.I.

Employee 10 NO. COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date Page 1 of 5

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2130220401/ PLOR-310CA KIA: 400000 A4.01 RO: 3.1 SRO: 3.0 TASK DESCRIPTION: Verify Isolation of Drywell Chilled Water and RBCCW (Alternate Path RBCCW is Supplying Drywell Chilled Water Loads)

A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" ..IPMs are designed to be performed in the simulator. If a "Control Room" ..IPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. ..IPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

Page 2 of 5

B. TOOLS AND EQUIPMENT None C. REFERENCES GP-8.B, Rev. 18 "PCIS Isolation - Groups II and III" (R)

D. TASK STANDARD

1. Satisfactory task completion is indicated when all of the following valves are closed:

Drywell Chilled Water isolation valves, MO-2200A & Band MO-2201A & B

RBCCW isolation valves, MO-2373 and MO-2374.

2. Estimated time to complete: 12 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform step 3.5 of GP-8.B "PCIS Isolation - Groups II and III".

I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. The Reactor has just been scrammed.

2. The Drywell Chilled Water System has been shutdown due to system leakage.

3. RBCCW is supplying DWCW loads.

4. DWCW return header pressure is 10 psig.

5. Drywell pressure is approximately 17 psig.

G. INITIATING CUE The Control Room Supervisor directs you to perform step 3.5 of GP-8.B, "PCIS Isolation Groups II and III".

Page 3 of 5

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain a copy of procedure GP-8.B. P A copy of procedure GP-8.B is obtained.

2 Verify MO-20245 AND MO-20246 aligned P MO-20245 AND MO-20246 red "RX BLDG in the "RX BLDG CLG WATER" position. CLG WATER" lights are lit. MO-20245 AND MO-20246 red "CHILLED WATER" lights are out at Panel 20C005A.

3 Calculate Corrected RBCCW Pressure P Indicated RBCCW pressure is checked, (CRP) by taking indicated RBCCW then 25 psig is subtracted to determine a pressure on PI-2350 - 25 psig. CRP of approximately 10 psig.

- NOTE**

Alternate Path starts with next step.

4 Compare Drywell pressure to Corrected P Corrected RBCCW Pressure (CRP) is RBCCW Pressure (CRP) to determine determined to be lower than PR-2508 or which pressure is greater. PR-4805 or PR-81 02A(B} at panels 20C003/20C004C.

5 Trip BOTH Recirc pumps. P A and B Recirc "DRIVE MOTOR" breaker green lights are verified ON at panel 20COO4A.

6 Close MO-2200A, Drywell Chilled Water P MO-2200A control switch is momentarily Header Supply isolation valve. placed in the "CLOSE" position at panel 20C012.

7 Verify the MO-2200A, Drywell Chilled P MO-2200A green light is verified ON and Water Header Supply valve is closed. red light is verified OFF at panel 20C012.

8 Close MO-2200B, Drywell Chilled Water P MO-2200B control switch is momentarily Header Supply isolation valve. placed in the "CLOSE" position at panel 20C012.

9 Verify the MO-2200B, Drywell Chilled P MO-2200B green light is verified ON and Water Header Supply valve is closed. red light is verified OFF at panel 20C012.

10 Close MO-2201A, Drywell Chilled Water P MO-2201A control switch is momentarily Header Return isolation valve. placed in the "CLOSE" position at panel 20C012.

11 Verify the MO-2201A, Drywell Chilled P MO-2201A green light is verified ON and Water Header Return valve is closed. red light is verified OFF at pane120C012.

5

STEP ACT STANDARD

12 Close MO-2201 B, Orywell Chilled Water P MO-2201 B control switch is momentarily Header Return isolation valve. placed in the "CLOSE" position at panel 20C012.

13 Verify the MO-2201 B, Orywell Chilled P MO-2201 B green light is verified ON and Water Header Return valve is closed. red light is verified OFF at panel 20C012.

14 Close MO-2373, RBCCW ISOL valve. P MO-2373 control switch is momentarily placed in the "CLOSE" position at panel 20C012.

15 Verify MO-2373, RBCCW ISOL valve is P MO-2373 green light is verified ON and closed. red light is verified OFF at panel 20C012.

16 Close MO-2374, RBCCW ISOL valve. P MO-2374 control switch is momentarily placed in the "CLOSE" position at panel 20C012.

17 Verify MO-2374, RBCCW ISOL valve is P MO-2374 green light is verified ON and closed. red light is verified OFF at panel 20C012.

18 Verify all the Drywell cooler fans are P The following Drywell cooler fan green tripped. lights are verified ON at panel 20C012:

2AV026A, 2AV026B 2 BV026A, 2BV026B 2CV026A, 2CV026B 2DV026A,2DV026B 2EV026A,2EV026B 2FV026A, 2FV026B 2GV026A, 2GV026B 19 Inform Control Room Supervisor of task P Task completion reported.

completion.

20 As an evaluator, ensure that you have P Positive control established.

positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND I procedures.

Under "ACT" P - must perform S - must simulate TERMINATING CUE When step 3.5 of GP-8.B has been completed, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

Page 5 of 5

TASK CONDITIONS/PREREQUISITES

1. The Reactor has just been scrammed.

2. The Drywell Chilled Water System has been shutdown due to system leakage.

3. RBCCW is supplying DWCW loads.

4. DWCW return header pressure is 10 psig.

5. Drywell pressure is approximately 17 psig.

INITIATING CUE The Control Room Supervisor directs you to perform step 3.5 of GP..S.B, "PCIS Isolation - Groups II and III".

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET Peach Bottom TYPE: JPM D QUALIFICATION MANUAL D OJT MODULE Licensed Operator Requalification Licensed Operator Requalification J. W. Lyter v Defeat of RCIC Interlocks (Unit 2)

APPROVALS:

Signature I Title Date APPROVED FOR USE:

Signature I Title Date EFFECTIVE DATE: -----

NAME: ISSUE DATE:

Last First M.1.

Employee 10. NO. COMPLETION DATE:

COMMENTS:

Training Review for Completeness: PIMS CODE:

PIMS ENTRY:

Signature/Date

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2002200501/ PLOR-156P KIA: 210000 A4.07 URO: 3.9 SRO: 3.8 TASK DESCRIPTION: DEFEAT OF RCIC INTERLOCKS (UNIT 2)

A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this ..IPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical ..IPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

Page 2 of 5

B. TOOLS AND EQUIPMENT

1. T-251 Tool Package

2. EOP Tool Locker Key C. REFERENCES T-251-2, Rev. 5, "RPV Pressure Control Using RCIC" D. TASK STANDARD

1. Satisfactory task completion is indicated when Relay contacts have been booted per Step 4.1 of T-251-2.

2. Estimated time to complete: 12 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to defeat Unit 2 RCIC interlocks using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Unit 2 scrammed.

2. Use of this procedure has been directed by TRIP procedures.

3. Water is available from the CST and RCIC suction is aligned to the CST.

4. RCIC is available.

G. INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to perform Step 4.1 of T-251-2, "RPV Pressure Control Using RCIC".

Page 3 of 5

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD

1 Obtain the key for the Emergency S Emergency Operating Procedure Tool Operating Procedure Tool Locker. Locker Key requested from WECS OR (Cue: When examinee requests EOP examinee identifies the location of the Tool Locker key from WECS OR WECS key box and its associated key.

examinee identifies the location of the WECS key box and its associated key then evaluator should provide the EOP Tool Locker key.)

2 Open Emergency Operating Procedure P Tool Locker located on Radwaste Building Tool Locker and obtain T-251 Tool Kit. EI. 165' is unlocked, opened and T-251 Tool Kit is located.

(Cue: Equipment obtained.)

- - - NOTE****

When examinee locates tool kit, inform him that he now has the tools to perform the procedure. Provide the examinee with a copy of the T-200 procedure which corresponds to the tool kit that has been chosen. DO NOT allow equipment to be removed from the locker. Relock the locker before leaving the area.

3 Remove front cover from relay 13A-K1. S The two front cover fasteners are turned COUNTERCLOCKWISE until loose, front (Cue: Cover is removed.) cover is then pulled from the face of relay 13A-K1 at panel 20C34 [FRONT] in the Cable Spreading Room.

4 Boot contact 5-6 on relay 13A-K1. S The THIRD FROM THE RIGHT relay contact arm is moved away from its (Cue: Boot is installed.) mating contact and a boot from the tool kit is placed over the contact arm.

5 Boot contact 11-12 on relay 13A-K 1. S The FAR LEFT relay contact arm is moved away from its mating contact and a (Cue: Boot is installed.) boot from the tool kit is placed over the contact arm.

6 Replace front cover on relay 13A-K1. S Front cover is held in place while turning the two front cover fasteners (Cue: Cover is replaced.) CLOCKWISE until tight.

Page 4 of 5

STEP NO STEP ACT STANDARD 7 Remove front cover from relay 23A-K1. S The two front cover fasteners are turned COUNTERCLOCKWISE until loose, front (Cue: Cover is removed.) cover is then pulled from the face of relay 23A-K1 at panel 20C39 [FRONT] in the Cable Spreading Room.

8 Boot contact 3-4 on relay 23A-K1. S The SECOND FROM THE RIGHT relay contact arm is moved away from its (Cue: Boot is installed.) mating contact and a boot from the tool kit is placed over the contact arm.

9 Replace front cover on relay 23A-K1. S Front cover is held in place while turning the two front cover fasteners (Cue: Cover is replaced.) CLOCKWISE until tight.

10 Remove front cover from relay 23A-K4. S The two front cover fasteners are turned COUNTERCLOCKWISE until loose, front (Cue: Cover is removed.) cover is then pulled from the face of relay 23A-K4 at panel 20C39 [FRONT] in the Cable Spreading Room.

11 Boot contact 5-6 on relay 23A-K4. S The THIRD FROM THE RIGHT relay contact arm is moved away from its (Cue: Boot is installed.) mating contact and a boot from the tool kit is placed over the contact arm.

12 Replace front cover on relay 23A-K4. S Front cover is held in place while turning the two front cover fasteners (Cue: Cover is replaced.) CLOCKWISE until tight.

13 Inform Control Room of task completion. S Task completion reported using telephone or GAI-TRONICS page system.

(Cue: Control Room acknowledges report.) NOTE: Hand held radio is NOT to be used in the Cable Spreading Room.

14 As an evaluator ensure you have positive P Positive control established control of all exam material provided to the examinee (Task Conditions/Prerequisites)

AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When Step 4.1 of T-251-2, "RPV Pressure Control Using RCIC" is complete, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

Page 5 of 5

TASK CONDITIONS/PREREQUISITES

1. Unit 2 scrammed.

2. Use of this procedure has been directed by T-100 procedures.

3. Water is available from the CST and RCIC suction is aligned to the CST.

4. RCIC is available.

INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to perform Step 4.1 of T -251-2, "RPV Pressure Control Using RCIC".

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET ch Bottom Commo

~ JPM QUALIFICATION MANUAL OJT MODULE Licensed Operator Training LICENSED OPERATOR REQUALIFICATION 000 C. N. Croasmun cnc Bypass of SV-9130A and SV-9130B APPROVALS:

Signature I Title Date APPROVED FOR USE:

EFFECTIVE DATE: _ _---.: _ _ _._ __

NAME: ISSUE DATE:

Last First M.1.

EMPLOYEE ID NO. COMPLETION DATE:

COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Signature/Date

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: Task# 2008450599/ PLOR-275P KIA: 218000 K4.04 RO: 3.5 SRO: 3.6 TASK DESCRIPTION: Perform EO Actions to Bypass SV-9130A&B, ADS Nitrogen Supply A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. JPM completion time requirement is met.

1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

B. TOOLS AND EQUIPMENT

1. Copy of T-331-3 Area 31 Fire Guide Attachment 1 C. REFERENCES

1. T-331-3 Area 31 Fire Guide D. TASK STANDARD

1. Satisfactory task completion is indicated when a bypass around the SV-9130A & B valves has been installed ..

2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform the necessary steps to install a bypass around the SV 9130A and SV-9130B valves using the appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. A fire has occurred in the 3A and 3C Emergency Battery Room.

2. The ADS valves do NOT currently have a long term pneumatic supply.

G. INITIATING CUE The Control Room Supervisor directs you to perform T-331-3 Attachment 1 to install a bypass around the SV-9130A and SV-9130B valves.

Page 3 of6

H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 Obtain a copy of T-331-3 Attachment 1. S Copy of Attachment 1 obtained.

(Cue: Provide the candidate with a copy of T -331-3 Attachment 1.)

2 Obtain bypass line for SV-9130A. S Remove bypass line for SV-9130A from its holder on the wall.

(Cue: Bypass line has been removed.)

3 Remove FME plugs. S Remove FME plugs from the female Parker fittings on each end of the bypass (Cue: FME plugs have been removed.) line.

- - - NOTE: ****

Next two steps are not sequence dependant.

4 Install bypass line. S INSTALL one end of the bypass line on the Parker fitting downstream of HV-3 16A-33155A ("ADS Backup N2 Sup Test Tap Upstream of SV-3-16A-9130A") by (Cue: Bypass line INSTALLED.) matching the bypass line and test tap color codes.

5 Install bypass line. S INSTALL the other end of the bypass line on the Parker fitting downstream of HV-3 16A-33156A ("ADS Backup N2 Sup Test Tap Dwnstrm of SV-3-16A-9130A") by

(Cue: Bypass line INSTALLED.) matching the bypass line and test tap color codes.

I

- - - NOTE: ****

Next two steps are not sequence dependant.

6 Open Test Tap Isolation Valve to bypass S OPEN HV-3-16A-33155A "ADS Backup nitrogen around SV-9130A. N2 Sup Test Tap Upstream of SV-3-16A 9130A" by rotating the handwheel counter (Cue: Test Tap isolation valve OPEN.) clockwise to the full OPEN position.

7 Open Test Tap Isolation Valve to bypass S OPEN HV-3-16A-33156A "ADS Backup nitrogen around SV-9130A. N2 Sup Test Tap Dwnstrm of SV-3-16A 9130A" by rotating the handwheel counter (Cue: Test Tap isolation valve OPEN.) clockwise to the full OPEN position.

STEP STEP ACT STANDARD NO 8 Verify nitrogen supply pressure. S VERIFY supply pressure is >85 psig on PI-9130, "ADS Backup Nitrogen Supply (Cue: PI-9130 is reading 92 psig.) Press" at RB SWel. 135'.

9 Notify the Control Room S Notify the Main Control Room that SV 9130A "ADS Backup Nitrogen A HDR (Cue: Control Room notified.) Supply to Drywell" bypass line is in service.

10 Obtain bypass line for SV-9130B. S Remove bypass line for SV-9130B from its holder on the wall.

(Cue: Bypass line has been removed.)

11 Remove FME plugs. S Remove FME plugs from the female Parker fittings on each end of the bypass (Cue: FME plugs have been removed.) line.

- - - NOTE: ****

Next two steps are not sequence dependant.

12 Install bypass line. S INSTALL one end of the bypass line on the Parker fitting downstream of HV-3 16A-33155B ("ADS Backup N2 Sup Test Tap Upstream of SV-3-16A-9130B") by (Cue: Bypass line INSTALLED.) matching the bypass line and test tap color codes.

13 Install bypass line. S INSTALL the other end of the bypass line on the Parker fitting downstream of HV-3 16A-33156B ("ADS Backup N2 Sup Test Tap Dwnstrm of SV-3-16A-9130B") by (Cue: Bypass line INSTALLED.) matching the bypass line and test tap color codes.

- - - NOTE: ****

Next two steps are not sequence dependant.

14 Open Test Tap Isolation Valve to bypass S OPEN HV-3-16A-33155B "ADS Backup nitrogen around SV-9130B. N2 Sup Test Tap Upstream of SV-3-16A 91308" by rotating the handwheel counter (Cue: Test Tap isolation valve OPEN.) clockwise to the full OPEN position.

15 Open Test Tap Isolation Valve to bypass S OPEN HV-3-16A-331S6B "ADS Backup nitrogen around SV-9130B. i N2 Sup Test Tap Dwnstrm of SV-3-16A 9130B" by rotating the handwheel counter (Cue: Test Tap isolation valve OPEN.) clockwise to the full OPEN position.

STEP STEP ACT STANDARD NO 16 Verify nitrogen supply pressure. S VERIFY supply pressure is >85 psig on PI-9130, "ADS Backup Nitrogen Supply (Cue: PI-9130 is reading 92 psig.) Press" at RB SWel. 135'.

17 Notify the Control Room S Notify the Main Control Room that SV 9130B "ADS Backup Nitrogen A HDR (Cue: Control Room notified.) Supply to Drywell" bypass line is in service.

18 As an evaluator ensure you have positive P Positive control established control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When a bypass has been installed around SV-9130A and SV-9130B, the Control Room Supervisor should be informed, the evaluator will terminate the exercise.

TASK CONDITIONS/PREREQUISITES

1. A fire has occurred in the 3A and 3C Emergency Battery Room.

2. The ADS valves do NOT currently have a long term pneumatic supply.

INITIATING CUE The Control Room Supervisor directs you to perform T..331-3 to install a bypass around the SV -9130A and SV -9130B valves.

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET

~ JPM D QUALIFICATION MANUAL OJT MODULE Licensed Operator Training Licensed Operator Requalification 001 J.1. Hanley jth Diesel Driven Fire Pump Manual Start APPROVALS: Signature I Title Date Signature I Title Date I Title Signature I Title Date APPROVED FOR USE: Signature I Title Date EFFECTIVE DATE:

NAME: ISSUE DATE:

Last First M.1.

Employee 10. NO. COMPLETION DATE:

I COMMENTS:

Training Review for Completeness: LMS CODE:

LMS ENTRY:

Sig nature/Date

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2860080101/ PLOR-327PA KIA: 286000A4.06 RO: 3.4 SRO: 3.4 TASK DESCRIPTION: Diesel Driven Fire Pump Manual Start A. NOTES TO EVALUATOR:

1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.

2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.

3. JPM Performance

a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).

b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.

4. Satisfactory performance of this JPM is accomplished if:

a. The task standard is met.

b. ..IPM completion time requirement is met.

1) For non-time critical ..IPMs, completion within double the estimated time (listed in paragraph D.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.

2) For time critical ..IPMs, completion within the estimated time (listed in paragraph D.2) is required.

5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.

B. TOOLS AND EQUIPMENT

1. Diesel Driven Fire Pump Room door key (#3702)

C. REFERENCES

1. SO 37B.1.B Rev 6, "Fire Water System Pump Manual Startup"_

D. TASK STANDARD

1. Satisfactory task completion is indicated when the Diesel Driven Fire Pump battery status circuit has been reset and the Diesel Driven Fire Pump has been started locally in accordance with SO 378.1.B, "Fire Water System Pump Manual Startup."

2. Estimated time to complete: 8 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to locally start the Diesel Driven Fire Pump using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Fire Water system is lined up for operation in accordance with SO 37.1.A, "Common Plant Fire Water System Lineup for Automatic Operations."

G. INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to locally start the Diesel Driven Fire Pump in accordance with SO 37B.1.B, "Fire Water System Pump Manual Startup."

H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 Obtain a copy of procedure SO 37B.1.8. P A copy of procedure SO 378.1.B is obtained. Section 4.1 is referenced.

2 Verify blue "Battery Connected" lights are S Determine that Blue "Battery 'A' lit. Connected" and "Battery 'B' Connected" lights are NOT lit.

(Cue: Blue battery status lights are NOT lit.)

3 Notify Shift Management that Battery P Notifies Shift Management.

Connected lights are NOT lit.

(Cue: Acknowledge report) 4 Open the Panel OOC126 door. S Panel door handle is turned, and door pulled outward to gain access to the (Cue: Panel door is open.) DDFP controls inside Panel OOC 126.

(Simulation is acceptable since the DDFP controls are visible through a window on the panel door.)

5 Turn the Diesel Driven Fire Pump Local S "Diesel Driven Fire Pump Local Control Control SW HS-O-37D- CS1/12' to "OFF". SW HS-O-37D- CS 1/12'" switch placed in "OFF" inside Panel OOC126.

(Cue: Diesel Driven Fire Pump Local Control SW HS-O-37D- CS1/12'switch has been placed in "OFF".)

6 Momentarily depress the "RESET" S "RESET" pushbutton momentarily pushbutton. depressed inside Panel OOC126 (right hand side).

(Cue: "RESET" pushbutton has been depressed. )

7 Turn the Diesel Driven Fire Pump Local S Diesel Driven Fire Pump Local Control Control SW HS -O-37D-CS1/12' to SW HS -O-37D-CS 1/12' switch placed in "AUTO". "AUTO" inside Panel OOC126.

(Cue: Control Selector switch has been placed in "AUTO". The blue "Battery Ready" lights are lit.)

8 Verify the blue "Battery A(B) Connected" S Determine that blue "Battery Ready" lights are lit. lights are lit (Cue: The blue "Battery Ready" lights are lit.)

STEP STEP ACT STANDARD NO

9 Place the Diesel Driven Fire Pump Local S Inside Panel 00C126, Diesel Driven Fire control switch HS-0-37D-CS1/12 in the Pump Local control switch HS-0-37D "MANUAL A" or "MANUAL 8" position CS1/12 placed in the "MANUAL A" or and depress the "START" pushbutton "MANUAL 8" position and the "START" pushbutton depressed (left hand side)

(Cue: Control switch manipulation is complete. Cylinder combustion noise is heard, DDFP engine speed rises to 1750 RPM as indicated on skid mounted panel and pump discharge pressure rises to 150 psig on PI-0290 near South wall of the DDFP.)

10 Place the Diesel Driven Fire Pump Local S Diesel Driven Fire Pump Local control control switch HS-0-37D-CS1/12 in the switch HS-0-37D-CS1/12 placed in the "TEST" position "TEST" position with NO pause at "AUTO" position (Cue: Control Selector switch has been placed in "TEST".)

11 Close the Panel OOC 126 door. S Panel door is closed and relatched using handle.

(Cue: Panel door is closed and relatched. )

12 Inform Control Room Supervisor of task P Task completion reported using hand completion. held radio, telephone or GAI-TRONICS page system.

(Cue: Control Room Supervisor acknowledges report.)

13 As an evaluator, ensure you have positive P Positive control established.

control of all exam material provided to the examinee (Task Conditions I Prerequisites) AND procedures.

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When then Diesel Driven Fire Pump battery status circuit has been reset and the Diesel Driven Fire Pump has been locally started, then Control Room Supervisor should be informed. The evaluator will then terminate the exercise.

TASK CONDITIONS/PREREQUISITES Fire Water system is lined up for operation in accordance with SO 37.1.A, "Common Plant Fire Water System Lineup for Automatic Operations."

INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to locally start the Diesel Driven Fire Pump in accordance with SO 378.1.8, "Fire Water System Pump Manual Startup."

Scenario Outline ES-D-I Simulation Facility Peach Bottom Scenario No. #1 Op Test No. 2013 NRC Examiners Operators _ _ _ _ _ _ _ _ CRS (SRO)

_ _ _ _ _ _ _ _ URO (ATC)

_ _ _ _ _ _ _ _ PRO (BOP)

Scenario The scenario begins with the reactor at 100% power.

Summary Following shift turnover, the crew will stroke Main Steam Sample Valves AO-2-02-316 and 317 as part of a surveillance test for primary containment isolation valves. Shortly after stroking the valves, Reactor Building to Torus vacuum breaker isolation valve AO-2502A will fail partially open requiring the crew to declare the valve inoperable per Technical Specifications.

Next, the running Service Water pump will trip on overcurrent, requiring the crew to place the standby pump in service using the system operating procedure. Following this, a drywell pressure instrument will fail upscale without causing the expected half scram. The crew will apply Tech Specs and (with time compression) insert a half scram lAW GP-25 "Installation of Tripsllsolations to Satisfy Tech SpecfTRM Requirements" .

Next the 'A' Condensate pump will trip without the expected Recirc System runback. Power must be manually reduced using recire flow to prevent a lOW-level scram.

When conditions have stabilized, #2 Auxiliary Bus will trip on overcurrent, causing a loss of the remaining Condensate pumps. HPCI and RCIC will initiate on low RPV level. The HPCI system flow controller will fail in automatic and must be adjusted in manual to allow the system to inject. The HPCI system will trip shortly after it injects and will not be recoverable. An RPS failure will prevent the automatic and manual scrams, requiring entry into T-101 "RPV Control" and the use of Alternate Rod Insertion (ARI) to shutdown the reactor. A small Reactor coolant leak will occur in the drywell and require the use of containment sprays. The crew should enterT-102 "Primary Containment Control". A containment spray logic failure will complicate the crew's efforts to spray containment. The crew will not be able to spray containment with the initial loop of RHR selected. The other loop of RHR will be available and should be used to spray containment.

The reactor coolant leak inside the drywell will be greater than the capacity of RCIC (the only remaining high-pressure feed source). The crew should enter T-111 "Level Restoration". As level deteriorates, the crew should start available low pressure ECCS pumps and when it is determined that level cannot be restored and maintained above -172 inches, the reactor should be depressurized in accordance with T-112 "Emergency Blowdown". Low pressure ECCS will be available to recover reactor level. The scenario will be terminated when the reactor has been depressurized and reactor level has been recovered and controlled.

Initial IC-118, 100% power Conditions Turnover See Attached "Shift Turnover" Sheet Event Malfunction Event Event No. No. Type* Description 1 See Scenario Guide N PRO Stroke time primary containment isolation valves for surveillance CRS testing 2 See Scenario Guide TS CRS Reactor Bldg to Torus vacuum breaker isolation valve fails open (Tech Spec) 3 See Scenario Guide C URO Service Water pump trip I manual start of the standby pump CRS 2013 NRC Scenario # I T-Ill Low Level, Rev I

Event Malfunction Event Event No. No. Type* Description 4 See Scenario Guide I PRO Drywell pressure instrument fails upscale without the expected half TS CRS scram (Tech Spec) 1 insert half scram lAW GP-25 5 See Scenario Guide R URO Condensate pump trip with recirc runback failure 1 power reduction CRS 6 See Scenario Guide M ALL Loss of #2 auxiliary bus 1 loss of condensate & feedwater 1 reactor coolant leak inside the drywell 7 See Scenario Guide C URO RPS failure requires ARI to scram the reactor CRS 8 See Scenario Guide C PRO HPCI controller fails in automatic CRS 9 See Scenario Guide C ALL HPCI turbine trip, requiring an emergency blowdown to restore level with low-pressure ECCS 10 See Scenario Guide I PRO Containment spray logic failure hampers effort to spray the CRS containment, requiring crew to use alternate RHR loop

(N)ormal, (R)eactlVlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec 2013 NRC Scenario # IT-Ill Low Level, Rev 1

SIMULATOR OPERATOR INSTRUCTIONS FOR 2013 NRC SCENARIO #1 GENERAL REQUIREMENTS

Recorders will be rolled prior to the scenario and paper from selected recorders will be retained for the examination team as requested.

All procedures, flow charts, curves, graphs, etc. will be in their normal storage places.

All markable procedures, boards, etc. will be erased.

All paper used by the crew will be retained for the examination team as requested.

The simulator operators will keep a log of all communications during the scenario as requested by the examination team.

SCENARIO SOURCE HISTORY

A previous version was used on the 2009 NRC ILT exam. It was modified (altered) slightly and submitted as a spare scenario for the 2011 NRC ILT exam. It has been modified again for use in the 2013 ILT 11-1 NRC Exam.

INITIAL SETUP Initial Conditions

IC-118, 100% power

Ensure recorder power is on; roll recorders as required

Ensure annunciator horns are active

Setup a TRIP Table PMS screen by typing in "NCPCIS" on the GROUP DISPLAY screen to support ST-0-007-420-2 performance in Event 1 Blocking Tags

None Activate APP "2013_NRC_SCN1" or insert the following:

Event Triggers TRG E5 ARI_A_DEPRESSED

=

TRG E4 BAT BUS_2_0VERCURRENT_LOCKOUT

=

TRG E5 MRF ARI01TO NORMAL Malfunctions IMF SWS01 B (E1 00) ('8' Service Water pump trip)

IMF MCS05A (E3 0 0) CA' Condensate pump trip)

IMF RRS20 (E4 2:00 O) 4 20:00 0 (Recirc loop rupture at 4% severity, 2 minute delay and 20 minute ramp)

IMF HPC03 (E6 0 0) (HPCI turbine trips)

IMF HPC04 (E4 0 0) (HPCI flow controller fails low in auto) 2013 NRC Scenario # 1 - T -111 Low Level, Rev 1

Overrides lOR ZLORP15DS26B (none 0 O) ON (5A-DS268 light at RPS Panel 20C017 to ON) lOR ZYP06A521S16 FALSE (SFCS recirc runback inhibit) lOR ZYP12A1S19 (none 0 0) OFF (Override Switch 10A-17A, prevents containment sprays) lOR ZYP12A3S19 (none 0 0) OFF (Override Switch 10A-17B, prevents containment sprays) lOR AN0205LD4 (E2 0 0) ALARM_ON (RPS INSTRUMENT GROSS FAILURE - 210 D-4) lOR AN0205LF1 (E2 0 0) ALARM_ON (DW HI PRESSURE - 210 F-1) lOR ZLOPC03A02502A_2 (E7 0 0) ON (AO-2502A red light on) lOR AN0203CE3 (E7 0 0) ALARM_ON (A TORUS VACUUM RELIEF VALVE OPEN - 224 E-3)

Trip Overrides MRF ARI01TO OVERRIDE (prevents ARI auto-initiation on 'A' channel)

MRF RPS03TO OVERRIDE (prevents RPS B1 trip)

MRF RPS04TO OVERRIDE (prevents RPS B2 trip)

MRF RPS06TO OVERRIDE (prevents RPS 83 trip)

Batch Files (Verify the following Batch File exists - DO NOT ENTER AT THIS TIME)

BAT BUS_2_OVERCURRENT_LOCKOUT IMF MAP06D IMF MAP06E IMF MAP06F lOR AN0209LA2 ALARM_ON lOR AN0209LC4 ALARM_OFF lOR ZYP14A3S04 TRIP lOR ZYP14A3S08 TRIP lOR ZYP14A3S37 TRIP Turnover Procedures ST-0-007-420-2 "PCIS Normally Closed Valves Operability Test", marked complete up to and including step 6.1.5 (rev 17) 20 J 3 NRC Scenario #1 - T-III Low Level, Rev I

SIMULATOR OPERATOR DIRECTIONS EVENT 1 Support crew for stroking of main steam sample valves AO-316 and 317 per ST-O 007-420-2.

EVENT 2 After stroking of main steam sample valves AO-316 and 317 per ST-0-007-420-2 is complete, initiate ET7 for split indication on normally closed PCIV AO-2502A, and verify the following:

lOR ZLOPC03A02502A_2 (E7 0 0) ON, AO-2502A red light on

lOR AN0203CE3 (E7 0 O) ALARM_ON, A TORUS VACUUM RELIEF VALVE OPEN - 224 E-3 When dispatched as the Equipment Operator to the valve to verify ARC 224 E-3 step 3.c, wait 1 minute and report that the valve appears to be closed and that you hear an air leak but cannot tell where it is coming from.

EVENT 3 After the Tech Spec evaluation is complete, or when directed by the Lead Examiner, initiate ET1 (IMF SWS01 B) to trip the '8' Service Water pump.

When requested to check the '8' Service Water pump breaker, report that it tripped on instantaneous overcurrent.

Support the crew while placing the 'C' Service Water pump in service lAW SO 30.1.A-2, section 4.2. When dispatched as the Equipment Operator for a start of the 'C' Service Water, wait 2 minutes and report steps 4.2.3 and 4.2.4 are complete and the 2C SW Pump is ready for a start. Support the crew with step 4.2.7 after pump starts by reporting local service water pressure is 80 psig.

Support the crew while restoring the Fuel Pool Service Water booster pumps lAW SO 19.1.A-2, section 4.2. (Two pumps should be placed in service).

EVENT 4 When Fuel Pool Service Water is restored, or when directed by the Lead Examiner, initiate ET2 for the drywell pressure instrument failure, and verify the following:

lOR AN0205LF1 ALARM_ON, OW HI PRESSURE (210 F-1)

lOR AN0205LD4 ALARM_ON, RPS INSTRUMENT GROSS FAILURE (2100-4)

When requested to check the 2AC0650 and 28C0650 instrument racks, report Orywell Pressure Instrument PIS-2-5-12A is upscale high with the gross failure light lit. If directed to reset the gross failure, report that it will NOT reset.

IF I & C is contacted for support of Relay 5A-K4A failure, report that the relay must be replaced and it will take at least a shift to do so.

2013 NRC Scenario #1 - T-\\\ Low Level, Rev 1

SIMULA TOR OPERATOR DIRECTIONS EVENT 5 After the crew has inserted a half scram on RPS channel A 1 and before inserting a PCIS channel trip, or when directed by the Lead Examiner, initiate a trip of the 'A' condensate pump using ET3 (IMF MCS05A).

Recirc pumps will fail to automatically runback due to a pre-inserted override (lOR ZYP06A521S16 FALSE).

When requested to check the 'A' condensate pump breaker, report that it tripped on instantaneous overcurrent. If dispatched to the 'A' condensate pump, wait 2 minutes and report there is nothing abnormal.

Support the crew as necessary during the power reduction.

Support the crew during performance of SO 5.2.A-2 "Condensate System Condensate Pump Shutdown" EVENTS 6 When actions for the condensate pump trip are complete, and when target power level of.::: 60% is achieved (or when directed by the Lead Examiner), initiate ET4 to cause an overcurrent lockout on #2 aux bus and fail the HPCI flow controller low, and verify the following:

Activate BAT BUS_2_0VERCURRENT_LOCKOUT, Loss of #2 Aux Bus

IMF HPC04, HPCI flow controller fails low in auto Verify a Recirc loop rupture initiates 2 minutes later at 4% severity on a 20 minute ramp (IMF RRS20 4 20:00). .

If asked, report DWCW return header pressure is 28 psig.

Support performance of T-223 "Drywell Cooler Fan Bypass" if requested to perform step 4.6 for placing the fan breakers in SLOW.

EVENT 7 RPS fails to scram automatically or manually (manual ARI works) - pre-inserted.

The 'A' ARI channel will fail to automatically initiate. When the URO arms the 'A' ARI channel, verify ET5 (MRF ARI01TO NORMAL) initiates to restore the 'A' ARI channel to normal.

When directed to close HV-2-3-56 (per T-246), MRF T220_2 CLOSE and report HV-2-3-56 is closed.

EVENT 9 30 to 60 seconds after HPCI automatically starts and is injecting, AND after operators take manual control, initiate ET6 (IMF HPC03) (HPCI turbine trips) in order to support maintaining RPV level -100 to -80 inches.

When directed to investigate the HPCI turbine trip, wait 5 minutes and then report unable to determine the cause of the trip.

2013 NRC Scenario # I - T-l11 Low Level, Rev I

SIMULATOR OPERATOR DIRECTIONS EVENT 10 Pre-inserted instrument failures will prevent the crew from spraying the torus or the drywell. .

After the crew attempts to spray the containment (either torus or drywell), delete the override on the OPPOSITE RHR LOOP:

To delete the override on the '8' RHR Loop, DOR ZYP12A3S19

To delete the override on the 'A' RHR Loop, DOR ZYP12A1S19 NOTE: Adjust the severity of RRS20 as necessary to control the pace of RPV level trend toward -172 inches. Ensure the crew has time to enter T -111 and inhibit ADS before raising the leak severity. Consider MMF RRS20 to 6% with remaining ramp time when HPCI is tripped. HPCI will likely restore RPV level to 0 inches before RRS20 initiates, even with RCIC OOS.

TERMINATION The scenario may be terminated after the reactor has been depressurized and reactor level has been recovered and is controlled.

2013 NRC Scenario #1 - T-l11 Low Level, Rev I

SHIFT TURNOVER PLANT CONDITIONS:

Unit 2 is steady at 100% power.

INOPERABLE EQlIIPMENT/LCOs:

None SCHEDULED EVOLUTIONS:

ST-O-007-420-2, "PCIS Normally Closed Valves Operability Test".

SURVEILLANCES DUE THIS SHIFT:

Completion of ST-O-007-420-2 "PCIS Normally Closed Valves Operability Test". The test is done up to and including step 6.1.5 (Rev 17). Continue with step 6.2 (stroking AO-2-02-316 and 317)

Stopwatch is available

PMS screen is setup to support ST ACTIVE CLEARANCES:

None GENERAL INFORMATION:

Unit 2 is steady at 100% power.

2013 NRC Scenario #1 - T-III Low Level, Rev 1

CRITICAL TASK LIST

1. Recognize failure of the Reactor Protection System to scram the reactor and initiate Alternate Rod Insertion (ARI) to insert control rods in accordance with T-101 "RPV Control" and RRC 3B.1-2 "Alternate Rod Insertion During A Plant Event".

2. Spray the drywell in accordance with T-204 "Initiation of Containment Sprays Using RHR" when conditions permit, but before drywell temperature exceeds 281 degrees F.

3. Perform an emergency blowdown in accordance with T-112 "Emergency Blowdown" when reactor water level cannot be restored and maintained above -172 inches.

2013 NRC Scenario # I - T -III Low Level, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 1 Page: 1of18 Event

Description:

Stroke main steam sample isolation valves AO-2-02-316 and 317 per ST-0 007-420-2 Cause: Stroke open and close PCIVs associated with Main Steam Sample System Effects: N/A - Normal evolution Position Applicant's Actions or Behavior CRS Directs the PRO to continue with ST-0-007-420-2 "PCIS Normally Closed Valves Operability Test" starting at step 6.2 (Rev 17).

PRO Performs step 6.2 of ST-0-007-420-2:

Strokes open AO-2-02-316 "Main Steam Sample Inboard" Strokes closed and times AO-2-02-316 "Main Steam Sample Inboard" Records time in surveillance test Strokes open AO-2-02-317 "Main Steam Sample Outboard" Strokes closed and times AO-2-02-317 "Main Steam Sample Inboard" Verifies PMS computer points associated with both valves have changed state by verifying historical tabular trend 2013 NRC Scenario #1 - T-III Low Level, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 2 Page: 2of18 Event

Description:

Reactor Building to Torus Vacuum Breaker Isolation Valve AO-2502A has split indication Cause: Deflation of boot seal for AO-2502A Effects: Valve is no longer leak tight and inoperable for primary containment purposes Position Applicant's Actions or Behavior PRO Acknowledges and reports alarm 224 E-3 "A TORUS VACUUM RELIEF VALVE OPEN" Verifies that AO-2502A is open CRS References ARC 224 E-3 Direct that an Equipment Operator be dispatched to check instrument air supply, backup nitrogen supply, and valve seal operation for AO-2502A.

Refer to Tech Spec 3.6.1.5 Declare AO-2502A inoperable per Tech Spec 3.6.1.5. Condition A Determine that AO 250A must be closed within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

2013 NRC Scenario #1 - T-lll Low Level. Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 3 Page: 30f18 Event

Description:

'B' Service Water pump trips on overcurrent Cause: Motor winding failure Effects: 1. Alarms:

216 H-1 "'B' Service Water Pump Trip"

216 H-2 B' Service Water Pump OVLD"

216 F-1 "Service Water Header La Press"

216 F-5 "Fuel Pool Service Water To HX La Press"

2. Loss of 'B' Service Water pump, requiring manual start of 'C' Service Water pump.

Time Position Applicant's Actions or Behavior lIRO/PRO Recognize and report the following alarms and enter corresponding Alarm Response Cards:

216 H-1 B' Service Water Pump Trip"

216 H-2 B' Service Water Pump OVLD"

216 F-1 "Service Water Header La Press"

216 F-5 "Fuel Pool Service Water To HX La Press" Recognize and report trip of the 2B Service Water pump.

Recognize and report trip of the 2A and 2B Fuel Pool Service Water (FPSW) booster pumps.

Green flag the 2B Service Water pump control switch.

(May) green flag the 2A and 2B FPSW booster pump control switches.

Dispatch an Equipment Operator to investigate the Service Water pump and breaker.

CRS Enter and direct actions of Alarm Response Cards 216 H-1, 216 H-2, 216 F-1 and 216 F-5.

Direct placing the 2C Service Water pump in service lAW SO 30.1.A-2 "Unit 2 Service Water System Normal Operations".

Request Maintenance assistance to investigate trip of 2B Service Water Pump.

PRO Place the 2C Service Water pump in service lAW SO 30.1.A-2 as follows:

Direct an Equipment Operator to prepare the 2C Service Water pump for start lAW SO 30.1.A-2, steps 4.2.3 and 4.2.4.

Start the 2C Service Water pump by placing the pump control switch in "Run".

Verify Service Water pump discharge pressure is 65-95 psig (both in the Control Room and locally).

2013 NRC Scenario It I - T-Ill Low Level, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 3 Page: 4of18 Event

Description:

'B' Service Water pump trips on overcurrent (continued)

Position Applicant's Actions or Behavior CRS Direct placing two Fuel Pool Service Water booster pumps in service lAW SO 19.1.A-2 "Fuel Pool Cooling System Startup and Normal Operations".

PRO Place two Fuel Pool Service Water booster pumps in service lAW SO 19.1.A-2 as follows:

Direct an Equipment Operator to prepare two Fuel Pool Service Water booster pumps for start lAW SO 19.1.A-2, step 4.2.5.

Start the 2A, B, or C Fuel Pool Service Water booster pump by placing the pump control switch in "Run".

Start an additional Fuel Pool Service Water booster pump by placing the pump control switch in "Run".

Direct an Equipment Operator to adjust differential pressure for the Fuel Pool Service Water booster pumps placed in service lAW SO 19.1.A-2, step 4.2.8.

CRS Request troubleshooting/technical assistance through the Shift Manager.

2013 NRC Scenario #1 - T-lll Low Level, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 4 Page: S of18 Event

Description:

Drywell pressure instrument fails upscale without the expected half scram Cause: PIS-2-5-12A fails upscale (gross failure)

Effects: 1. Alarms:

210 F-1 "Drywell Hi Pressure Trip"

210 D-4 "RPS/PCIS Trip Units in Calibration of Gross Failure"

2. Drywell pressure instrument fails high (gross failure); RPS half scram fails to occur.

Position Applicants Actions or Behavior URO Recognize and report the following alarms and enter the corresponding Alarm Response Cards:

210 F-1 "Drywell Hi Pressure Trip"

210 D-4 "RPS/PCIS Trip Units in Calibration of Gross Failure" Determine actual drywell pressure is below the scram setpoint.

Recognize and report the drywell pressure instrument failure did NOT cause the expected RPS half scram.

Evaluator CUE: IF RO investigates relay status, inform RO that SA K4A is DE-ENERGIZED.

CRS Enter and execute the Alarm Response Cards for 210 F-1 and 210 D-4.

Direct an Equipment Operator to check the 2A(B)C065D instrument racks in the Reactor Building to aid in determining the cause of the trip.

CRS Direct troubleshooting in accordance with the Alarm Response Card for 2100-4 "RPS/PCIS Trip Units in Calibration of Gross Failure".

Declare drywell pressure instrument PIS-2-5-12A inoperable.

Request I & C assistance to troubleshoot Drywell High Pressure Trip instrument failure and associated RPS failure Review Tech Spec 3.3.1.1 and determine Condition A applies (RPS Function 6 on Table 3.3.1.1-1):

Place associated channel (or trip system) in trip within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , OR

Be in Mode 3 within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Review Tech Spec 3.3.6.1 and determine Condition A applies (PCIS Function 2.b on Table 3.3.6.1-1):

Place associated channel (or trip system) in trip within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , OR

Be in Mode 3 in the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in Mode 4 in the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

Review Tech Spec 3.3.6.2 and determine Condition A applies (SCIS Function 2 on Table 3.3.6.2-1):

Place associated channel (or trip system) in trip within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , OR

Take the compensatory actions for Condition C.

Recognize that RPS/PCIS trips must be installed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

2013 NRC Scenario #1 T-Ill Low Level. Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 4 Page: 6 of 18 Event

Description:

Drywell pressure instrument fails upscale without the expected half scram (continued)

Position Applicant's Actions or Behavior NOTE: This section is optional at discretion of Lead Examiner.

The Lead Examiner may act as the Shift Manager and direct the crew to perform GP-25 to install the RPS/PCIS trips OR the scenario can move on when the crew determines that GP-25 Appendices 1 &

5 apply" CRS Initiate GP-25 Appendices 1 and 5 to install redundant RPS/PCIS trips.

PRO Install trip on A 1 RPS channel as directed by the CRS using GP-25 Appendix 1:

Complete Appendix 1.

Inform URO that a half scram on RPS channel A 1 will be inserted.

At Pane120C015, insert key and place the A1 Test Keylock Switch to the TRIP position.

NOTE: the next event will be initiated before the crew can perform Appendix 5 of GP-25 (PCIS).

2013 NRC Scenario # I - T-Ill Low Level, Rev 1

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 1 Event No.: 5 Page: 70f18 Event

Description:

'A' Condensate pump trip with Recirc runback failure / power reduction Cause: 'A' Condensate pump trips on overcurrent / relay failure in the Recirc runback logic Effects: 1. Alarms:

203 E-1 "A Condensate Pump Overload"

203 E-2 "A Condensate Pump BKR Trip"

2. Recirc automatic runback fails to occur, resulting in lowering reactor level and requiring manual recirc flow reduction to control reactor level.

Position Applicant's Actions or Behavior URO Recognize and report trip of the 'A' Condensate pump.

(May) recognize / report the Recirc pump runback (45%) failed to occur.

Recognize and announce entry into the OT-100 "Reactor Low Level":

Recognize the reactor water level drop is caused by a lack of makeup capability, requiring power reduction with Recirc flow.

Reduce power by lowering the 'A' and 'B' Recirc pump speed controllers per GP-9-2 "Fast Reactor Power Reduction" (this must be done in a controlled manner that does not result in level swell and a high level trip of the Reactor Feed pumps).

Recognize and announce entry into OT-112, "Unexpected/Unexplained Change in Core Flow".

NOTE: the crew must respond to this event by lowering power per GP-9 to prevent a low reactor water level scram. IF the crew recognizes that Feedwater flow was above 85% (12 Mlbm/hr) prior to the Condensate pump trip, they should reduce Recirc flow to the runback setpoint of 45%.

CRS Enter OT-100 "Reactor Low Level": direct the URO to lower power by lowering Recirc flow using GP-9-2 "Fast Reactor Power Reduction".

Enter OT-110 'Reactor High Level" if high level condition exists following power reduction.

Enter / direct actions of ARC 203 E-2 "A Condensate Pump BKR Trip".

Enter / direct actions of OT-112 "Unexpected/Unexplained Change in Core Flow".

Direct insertion of control rods per GP-9-2 "Fast Reactor Power Reduction" to exit Region 2 of Power to Flow map.

Plot conditions on Power to Flow map. Determine that plant is in region 2.

Direct the URO to monitor for THI (May) refer to GP-5 "Power Operations" to determine power must be limited to <80% total feedwater flow with 2 Condensate and 3 Reactor Feedwater pumps.

Request Maintenance assistance for investigation into trip of 'A' Condensate Pump and failure of Recirc system to runback.

2013 NRC Scenario #1 - T-III Low Level. Rev 1

Operator Actions Op Test No.: 1 Scenario No.: 1 Event No.: 5 Page: 8of18 Event

Description:

'A' Condensate pump trip with Recirc runback failure I power reduction (cont'd)

Position Applicant's Actions or Behavior URO Monitor for Thermal Hydraulic Instabilities (THI).

Insert control rods per GP-9-2 "Fast Reactor Power Reduction" to exit Region 2 of Power to Flow map.

PRO Investigate the cause of the 'A' Condensate pump trip using the applicable Alarm Response Card.

Direct an Equipment Operator to investigate the breaker and pump.

Green flag the 'A' Condensate pump control switch.

CRS Direct PRO to perform SO 5.2.A-2 "Condensate System Condensate Pump Shutdown" for the 2A Condensate Pump PRO Perform SO 5.2.A-2 "Condensate System Condensate Pump Shutdown" for the 2A Condensate Pump 2013 NRC Scenario #1 - T-III Low Level, Rev I

Operator Actions Op Test No.: 1 Scenario No.: 1 Event No.: 6 Page: 90f18 Event

Description:

Loss of #2 auxiliary bus (loss of Condensate and Feedwater)

Cause: Failure in the bus work results in an overcurrent condition and a bus lockout I RPS 'B' automatic and manual channel failure Effects: 1. Alarms:

219 A-2 "2 Aux Bus Overcurrent Relays"

219 B-2 "2 Aus Bus Lo Voltage"

2. #2 Auxiliary Bus breakers trip, de-energizing the bus and its loads

3. The immediate impact of loss of #2 Auxiliary Bus is the resultant loss of the remaining Condensate pumps, causing reactor water level to drop rapidly.

4. Full Reactor scram does not occur; manual ARI initiation is required.

5. Reactor level drop is greater because more time is spent under power conditions with no high-pressure injection.

Position Applicant's Actions or Behavior PRO Recognize and report the loss of #2 Auxiliary Bus.

CRS URO Recognize and report Reactor water level is dropping rapidly.

Attempt to manually scram the Reactor by placing the Mode Selector Switch in "Shutdown".

Attempt to scram 'B' RPS by depressing the manual scram pushbutton.

Recognize and report an RPS scram has failed to occur. (See Event #8)

Report entry into T-1 01 "RPV Control" for the ATWS condition.

CT CRS Direct the mode switch be placed in SHUTDOWN if not previously performed by URO.

Recognize a failure to scram condition exists; enter and execute T-101 "RPV Control".

For RC/Q:

Direct initiation of Alternate Rod Insertion (ARI) (See Event #8).

2013 NRC Scenario # I - T-lll Low Level, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 6 Page: 10 of 18 Event

Description:

Loss of #2 auxiliary bus (loss of Condensate and Feedwater)

Position Applicant's Actions or Behavior CRS Execute T-101 "RPV Control".

For RC/L:

Direct restoring reactor level to +5 to +35 inches with HPCI and RCIC.

For RC/P:

Direct instrument nitrogen bypassed and restored lAW GP-8E.

Direct reactor pressure stabilized below 1050 psig.

PRO Perform applicable scram actions:

Transfer 13 KV house loads (#1 bus only).

Trip main turbine at approximately 50 MWe.

Verify main generator lockout.

Verify Group II & III isolations and SGTS initiation.

Verify SDV vent and drain valves are closed.

Verify HWC isolated.

Verify recirc pumps are tripped.

Report PRO scram actions to the CRS

Monitor instrument air header pressure and drywell pressure; report instrument air header pressure is greater than drywell pressure.

PRO Bypass and restore drywell instrument nitrogen lAW RRC 94.2-2 or GP-8E.

Place AO-2969A control switch to "CLOSE".

Place AO-2969B control switch to "CLOSE".

Place Drywell Instrument Nitrogen Bypass Switch 16A-S 100 in the "BYPASS" position.

Place Drywell Instrument Nitrogen Bypass Switch 16A-S99 in the "BYPASS" position.

Place AO-2969A control switch to "OPEN".

Place AO-2969B control switch to "OPEN".

NOTE: this activity may be coordinated between the URO and the PRO.

URO/PRO Announce an additional entry condition for T-101 based on Reactor level below -48 inches.

Operate HPCI and RCIC to restore reactor level to +5 to +35 inches.

2013 NRC Scenario # 1 - T -111 Low Level. Rev 1

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 1 Event No.: 6 Page: 11 of 18 Event

Description:

Reactor coolant leak inside the drywell Cause: A leak develops on a weld joint on the suction piping of the "B" reactor recirculation pump after it tripped; the leak size propagates over time.

Effects: 1. Initial alarms:

210 F-2 "Drywell Hi-Lo Press"

225 A-4 "Drywell Hi-Lo Press"

2. Drywell pressure and temperature will rise at an increasing rate, eventually leading to a high drywell pressure alarm, ECCS automatic start signals, and PCIS isolation signals. Conditions will escalate requiring the use of containment sprays.

Time Position Applicant's Actions or Behavior URO/PRO Recognize and report alarms 210 F-2 "Drywell Hi-Lo Press" and 225 A-4 "Drywell Hi-Lo Press" and enter corresponding Alarm Response Cards.

CRS Enter and execute follow-up actions of OT-101 "High Drywell Pressure":

When drywell pressure reaches 2 psig, then enter T-101 "RPV Control" and T -102 "Primary Containment Control" and execute concurrently with OT-101.

Direct additional drywell cooling placed in service.

URO/PRO Maximize drywell cooling by placing all drywell cooler fans to RUN.

CRS Enter and execute T-102 "Primary Containment Control" when drywell pressure reaches 2 psig.

For PC/P:

Direct performance of GP-8.B "PCIS Isolations - Groups II and III"

Direct torus sprays initiated lAW T-204 "Initiation of Containment Sprays Using RHR".

For DWIT:

Direct drywell cooling maximized by performing T -223 "DW Cooler Fan Bypass".

For PC/G:

Direct CAD placed in service as time permits.

Re-enter T-102 when Torus level reaches 14.9 feet, and when Drywell temperature reaches 145 degrees F.

Direct an RPV depressurization to 500-600 psig.

2013 NRC Scenario #1 - T-ill Low Level, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 6 Page: 12 of 18 Event

Description:

Reactor coolant leak inside the drywell (continued)

Position Applicant's Actions or Behavior URO/PRO Monitor T-102 parameters (torus temperature, torus level, drywell pressure, torus pressure, drywell temperature) and provide trends to the CRS as appropriate.

lIRO/PRO Perform GP-8.B, report no isolations required.

PRO Spray the torus in accordance with T-204 "Initiation of Containment Sprays Using RHR" (see Event #10).

URO Maximize drywell cooling by performing T-223 "OW Cooler Fan Bypass".

Shutdown drywell cooling fans when directed.

Depressurize the RPV to 500-600 psig using bypass valves.

URO/PRO Place CAD in service when directed.

Monitor reactor level, and report to the CRS reactor level is continuing to lower.

CRS When drywell pressure and temperature plot within the safe region of the Drywell Spray Initiation Limit Curve:

Direct drywell cooling fans shut down.

CT

Direct drywell sprays initiated lAW T-204 "Initiation of Containment Sprays Using RHR".

CT PRO Spray the drywell in accordance with T-204 "Initiation of Containment Sprays Using RHR".

NOTE: the crew will also enter T-103, "Secondary Containment Control",

due to high main steam tunnel temperatures (points 1 and 16 on TR-2-13 139) but there are no substantive actions that are required.

2013 NRC Scenario #) - T - J 1) Low Level, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 7 Page: 13 of 18 Event

Description:

RPS failure requires Alternate Rod Insertion (ARI) to scram the reactor Cause: RPS 'B' automatic and manual channel failure Effects: Full Reactor scram does not occur; manual ARI initiation is required.

Position Applicant's Actions or Behavior CT CRS Recognize a failure to scram condition exists; enter and execute T-101 "RPV Control".

For RC/Q:

Direct initiation of Alternate Rod Insertion (ARI).

CT URO Initiate ARIIAW RRC 38.1-2 "Alternate Rod Insertion During a Plant Event":

Rotate the "A" and "8" ARI pushbutton collars to "Armed".

Depress the "A" and "8" ARI pushbuttons.

Verify the following ARI solenoid valves open:

o SV-2-03-141A o SV-2-03-142A o SV-2-03-1418 o SV-2-03-1428

Verify and report the scram air header is depressurizing.

Monitor and report when control rods begin to insert.

Verify APRMs are downscale and report to the CRS.

Report the status of reactor level control, reactor pressure control, and control rods.

2013 NRC Scenario # I - T -111 Low Level, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 8 Page: 14 of 18 Event

Description:

HPCI flow controller fails low in automatic Cause: HPCI flow controller internal malfunction while in automatic Effects: HPCI turbine speed will be too low to develop enough system discharge pressure to allow injection into the RPV. Controller must be placed in MANUAL and output raised manually to allow the system to inject.

Position Applicant's Actions or Behavior PRO Recognize that HPCI system automatic response is abnormal and that the system has low discharge pressure and no injection flow.

Place the HPCI system flow controller in MANUAL.

Using controller manual output knob, raise HPCI system speed high enough to develop enough discharge pressure to allow system injection into the RPV.

Report the abnormal HPCI response and actions taken to the CRS.

2013 NRC Scenario #1 - T-J II Low Level, Rev I

Operator Actions Op Test No.: 1 Scenario No.: 1 Event No.: 9 Page: 15 of 18 Event

Description:

HPCI turbine trip / emergency blowdown Cause: Instrument failure Effects: HPCI will trip while in-service, RPV level lowers requiring emergency blowdown Position Applicant's Actions or Behavior URO Recognize and report alarm 221 B-1 "HPCI Turb Trip" and enter the corresponding Alarm Response Card (as time permits).

Dispatch an Equipment Operator to determine the cause of the trip.

When report is received from the field, report to the CRS that there is no apparent cause for the HPCI trip.

CRS Direct SBlC initiation to augment reactor level control.

Direct T-246 "Maximize CRD Flow to the Reactor Vessel".

URO/PRO Initiate SBlC for reactor level control, as directed, using RRC 11.1-2 "SBlC Initiation During a Plant Event".

Perform T-246 "Maximize CRD Flow to the Reactor Vessel".

Direct an Equipment Operator to open HV-2-3-129 "CRDHS Bypass Valve for Pump Suction Filter"

Direct an Equipment Operator to check standby CRD Pump for start per step 4.4.

Start the standby CRD Pump.

Direct an Equipment Operator to open discharge valve for the CRD Pump placed in service HV-2-3-36A or B.

While monitoring CRD Pump motor amps, direct an Equipment Operator to throttle open HV-2-3-170 "Inlet Valve to Drive Water Filters"

Direct an Equipment Operator to place the standby drive water filter in service per step 4.S.

Fully open MO-2-3-020 on Panel 20C005A.

Close MO-2-2A-S029A and B on Panel 20C004A.

Verify CRD flow controller FIC-2-3-301 in MANUAL.

While monitoring CRD Pump motor amps, open AO-2-3-19A(B) "Flow Control" using FIC-2-3-301.

2013 NRC Scenario #1 - T-Ill Low Level, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 9 Page: 16 of 18 Event

Description:

HPCI turbine trip I emergency blowdown (continued)

Position Applicant's Actions or Behavior CRS After it is determined reactor level cannot be maintained above -172 inches, exit the RC/L leg of T-101 and enter/execute T-111 "Level Restoration":

Direct ADS inhibited.

Direct Core Spray and LPCI pumps started.

CT When reactor level drops to -172 inches, enter and execute T-112 "Emergency Slowdown":

Verify torus level is above 7 feet.

Verify reactor pressure is 50 psig above torus pressure.

Direct 5 ADS SRVs opened.

URO/PRO Inhibit ADS when directed.

CT Verify start of all available Core Spray and LPCI pumps.

When directed, manually open 5 ADS SRVs by placing their control switches in OPEN.

CRS After T -112 is executed, direct RPV injection maximized with all systems, subsystems, and alternate subsystems.

After it is determined reactor level can be maintained above -172 inches, exit T-111 and enter T-101 "RPV Control" at step RC/L-1.

Direct reactor level restored to +5 to +35 inches with Core Spray/RHR.

URO/PRO Maximize injection with all systems, subsystems, and alternate subsystems.

Restore and maintain reactor level +5 to +35 inches, as directed.

2013 NRC Scenario #1 - T-Ill Low Level, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 10 Page: 17 of 18 Event

Description:

Pressure instrument failure prevents using containment spray on 1 RHR loop Cause: Drywell pressure input to spray logic permissive not functioning Effects: Prevents containment spray using 8 (A) loop of RHR, resulting in Drywell temperature rising toward 281 degrees F (the A (B) loop of RHR is available).

Time Position Applicant's Actions or Behavior NOTE: the spray logic failure will effect whichever loop of RHR (8 or A) is first selected to spray the containment. The simulator operator will delete the associated override (failure) on the opposite RHR loop to allow spraying the containment with that loop.

PRO Spray the torus in accordance with T-204 "Initiation of Containment Sprays using RHR":

Verify System 1 and 2 Drywell Pressure Permits Containment Spray annunciators (224 D-3, 225 B-3) are lit

Place keylock switch 1OA-S 18 in "MANUAL OVERRI DE".

Momentarily place switch 10A-S17 in "MANUAL".

Open or verify open MO-2-10-39 "Torus Header".

Open or verify open MO-2-10-89 HPSW Hx Outlet".

Start a HPSW pump

Start an RHR pump ..

Close or verify closed MO-2-10-34 "Full Flow Test".

Throttle open MO-2-10-38 "Torus Spray" to obtain 1,000 gpm on FI-2 10-136.

Recognize and report inability to spray the torus (drywell) with the B (A) loop of RHR CT CT CRS Direct the operator to spray the torus (drywell) with the opposite loop of RHR CT PRO As directed, spray the torus (drywell) using the opposite loop of RHR in accordance with T-204 "Initiation of Containment Sprays using RHR" (refer to steps above for steps to spray the torus).

Spray the drywell per T -204 as follows:

Verify both recirc pumps are tripped

Verify all drywell COOling fans control switches are in OFF

Open MO-2-10-31

Open MO-2-10-26

Monitor torus and drywell pressure

Throttle MO-2-10-26 to adjust drywell spray as needed 2013 NRC Scenario #1 - T-lil Low Level, Rev I

Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 1 Event No.: 10 Page: 18 of 18 Event

Description:

Pressure instrument failure prevents using containment spray on 1 RHR loop POST SCENARIO EMERGENCY CLASSIFICATION:

Classification is an Alert lAW EAL MA2 ("Failure to Scram") OR FA1 ("Loss of Reactor Coolant System Barrier").

TERMINATION CRITERIA:

The scenario may be terminated when the reactor has been depressurized and reactor level has been recovered and controlled.

2013 NRC Scenario #1 - T-lll Low Level, Rev 1

Scenario Outline ES-D-l Simulation Facility Peach Bottom Scenario No. !!..#2=--_ __ Op Test No. 2013 NRC Examiners Operators CRS (SRO)

LIRa (ATC)

PRO (BOP)

Scenario The scenario begins with the reactor at 100% power. After taking the shift, the crew will perform the Summary Master Trip Solenoid Valve Routine Test.

Next, a turbine stop valve will fail closed, requiring the crew to execute OT-1 02 "Reactor High Pressure",

which will require reducing reactor power to less than or equal to 95% in accordance with GP-5 "Power Operations" .

Next, a failure in the controller for the 'A' Recirc M-G set will cause the Recirc pump speed to oscillate. The crew should recognize the changes in core and jet pump flows and "lock up" the 'A' Recirc pump. The crew should verify compliance with Technical Specifications for recirc loop flow differentials.

Next, a spurious HPCI initiation will occur due to a logic system failure. The crew should enter OT-1 04 "Positive Reactivity Insertion" and shutdown HPCI. This event will cause a steam leak from the HPCI system piping in the HPCI pump room, requiring the crew to enter and execute T-103 "Secondary Containment Control". Initial attempts to isolate HPCI using the Isolation Pushbutton results in "split" indication for the MO-2-23-15 and -16 steam supply valves. Operator should attempt manual closure of these valves. All attempts to isolate HPCI will be unsuccessful due to logic system and control switch failures. The leak will gradually worsen, requiring a reactor scram and entry into T-1 01 "RPV Control".

While performing scram actions, the PRO should recognize the generator lockout failure following the main turbine trip and manually open the generator output breakers and exciter field breaker. The URO should respond to the 'C' reactor feed pump discharge bypass valve failure by batch feeding through the 'C' reactor feedpump discharge valve. When depressurization using Bypass Valves is performed, Bypass valves will initially function normally but then fail closed, requiring operator to complete depressurization using SRVs.

Conditions will continue to deteriorate in the Reactor Building due to the HPCI steam leak. When the second Reactor Building area (Torus Room) exceeds its T-103 Action Level, the crew should perform a T-112 "Emergency Blowdown". The scenario will end when the RPV is depressurized and RPV level is being maintained with Condensate.

Initial IC-119, 100% power Conditions Turnover See Attached "Shift Turnover" Sheet Event Malfunction Event Event No. No. Type* Description 1 See Scenario Guide N PRO Perform the master trip solenoid valve routine test CRS 2 See Scenario Guide R LIRa Turbine stop valve fails closed / power reduction CRS 3 See Scenario Guide C URO 'A' Recirc pump speed oscillations (Tech Spec) / Lock up the 'A' TS CRS Recirc pump 4 See Scenario Guide C PRO Inadvertent HPCI initiation / shutdown HPCI (Tech Spec)

TS CRS 2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev 1

Event Malfunction Event Event No. No. Type* Descrij!tion 5 See Scenario Guide M ALL HPCI steam leak into secondary containment 6 See Scenario Guide C PRO HPCllsolation System pushbutton and control switch failure CRS 7 See Scenario Guide I PRO Generator lockout fails to occur following main turbine trip CRS 8 See Scenario Guide C LlRO 'C' reactor feedpump discharge bypass valve fails to open, CRS complicating post-scram and post-blowdown reactor level control 9 See Scenario Guide C LlRO Bypass Valves fail closed, depressurize using SRVs CRS 10 See Scenario Guide ALL Emergency blowdown due to exceeding Reactor Building temperature limits in more than one area

(N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec 2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev 1

SIMULATOR OPERATOR INSTRUCTIONS FOR 2013 NRC SCENARIO #2 GENERAL REQUIREMENTS

Recorders will be rolled prior to the scenario and paper from selected recorders will be retained for the examination team as requested.

All procedures, flow charts, curves, graphs, etc. will be in their normal storage places.

All markable procedures, boards, etc. will be erased.

All paper used by the crew will be retained for the examination team as requested.

The simulator operators will keep a log of all communications during the scenario as requested by the examination team.

SCENARIO SOURCE HISTORY

This scenario was altered from one originally developed for the 2011 NRC ILT Exam.

INITIAL SETUP Initial Conditions

IC-119, 100% power, created from IC-14

Ensure recorder power is on; roll recorders as required

Ensure annunciator horns are active Blocking Tags

None Activate APP "2013_NRC_SCN2", or insert the following:

Event Triggers TRG E8 HPCI_ISOLATION_DEPRESSED TRG E12 BYPASS_JACK_.OPEN Malfunctions IMF MTA03C (E1 00) (Turbine stop valve #3 fails closed)

IMF HPC02 (E2 0 0) (HPCI spurious automatic start)

IMF HPC07 (E3 0 0) 5 20:00 0 (HPCI steam supply line break)

IMF RFC04A (E4 0 0) 100 (Recirc M-G flow controller 'A' oscillations)

IMF EHH02L (E12 60 0) (Bypass Valve A-I Fails Closed)

Overrides lOR ZYP01A2A1S02 (none 0 0) NORMAL eC' RFP discharge startup bypass MO-B090) lOR ZYP13A1S07 (none 0 0) OPEN (HPCI steam line isolation valve MO-23-15) lOR ZYP13A1S05 (none 00) OPEN (HPCI steam line isolation valve MO-23-16) lOR ZLOHP04BM02315-1 (E80 0) ON (MO-2-23-15 Green Light ON) lOR ZLOHP04BM02316-1 (E80 0) ON (MO-2-23-16 Green Light ON) 2013 NRC Scenario #2 - T-I03 HPCI Steam Leak, Rev I

Remote Functions None Trip Overrides MRF HP004TO Override (HPCI isolation override - includes K27, K28, K36, K57 relays)

MRF MGA01TO Override (Main Generator 86 lockout relay)

Batch Files None Turnover Procedures

RT-O-010-402-2 "Master Trip Solenoid Valves Operability Test" (provide a consumable copy) 2013 NRC Scenario #2 - T-I03 HPCI Steam Leak, Rev 1

SIMULATOR OPERATOR DIRECTIONS EVENT 1 Support the crew as necessary for the Master Trip Solenoid Valves Routine Test.

EVENT 2 When directed by the Lead Examiner, initiate pending events on ET 1 (IMF MTA03C) to cause turbine stop valve #3 to fail closed.

If requested as I&C to investigate annunciator 201 H-1 "Feedwater Field Instrument Trouble", acknowledge request.

If directed to walk down accessible areas of EHC system components, report no apparent issues identified.

EVENT 3 When directed by the Lead Examiner, initiate pending events ET 4 (IMF RFC04A 100) to cause Recirc M-G flow controller 'A' oscillations.

EVENT 4 When directed by the Lead Examiner, initiate pending events on ET 2 (IMF HPC02) to cause a spurious start of HPCI.

If dispatched as the Equipment Operator to investigate the HPCI start, wait approximately 5 minutes and report no HPCI abnormalities.

EVENT 5 After the Tech Spec determination has been made, or when directed by the Lead Examiner, initiate pending events on ET 3 (IMF HPC07 5 20:00 0) to cause a HPCI steam supply line break.

Modify the leak severity as necessary to control the scenario pace and ensure a second Reactor Building area exceeds the Action Level for temperature.

This will vary based on the crew's action to depressurize the reactor.

Event 6 When the PRO attempts to isolate HPCI using the Isolation Pushbutton, verify ET 8 initiates to activate pre-inserted overrides resulting in the MO-15 and -16 valves indicating "splits" but remaining fully open.

EVENT 7 Following the GP-4 shutdown and Main Turbine Trip, the Main Generator will not lockout.

EVENT 8 When the URO attempts to establish reactor level control using MO-B090, the valve will not open.

EVENT 9 When the URO attempts to depressurize using Bypass valves by using the manual BPV jack, verify ET 12 initiates to activate pre-inserted malfunctions to cause Bypass valves to close approx 60 seconds after initial opening.

EVENT 10 When the second area temperature exceeds the action level, the CRS will direct an emergency blowdown. The CRS may have directed a rapid depressurization with bypass valves prior the second parameter exceeding the action level.

TERMINATION The scenario may be terminated when 5 SRVS are open, the reactor is depressurized, and reactor level is under control.

2013 NRC Scenario #2 - T-103 HPC[ Steam Leak, Rev 1

SHIFT TURNOVER PLANT CONDITIONS:

Unit 2 is at 100% power.

INOPERABLE EQUIPMENT/LCOs:

None SCHEDULED EVOLUTIONS:

RT-O-01D-402-2 "Master Trip Solenoid Valves Operability Test" (provide a consumable copy)

SURVEILLANCES DUE THIS SHIFT:

RT-O-01D-402-2 "Master Trip Solenoid Valves Operability Test" ACTIVE CLEARANCES:

None GENERAL INFORMATION:

None 2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev 1

CRITICAL TASK LIST

1. Following a positive reactivity addition, restore Reactor power below 100%.

2. When a Primary System is discharging into Secondary Containment through an unisolable leak, scram the Reactor when any parameter (temperature) exceeds a T-103 "Secondary Containment Control" Action Level.

3. Perform T-112 "Emergency Blowdown" when the same parameter (temperature) exceeds a T-103 "Secondary Containment Control" Action Level in more than one area and the system breach has not been isolated.

2013 NRC Scenario #2 - T-I03 HPCI Steam Leak, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 1 Page: 1 of 14 Event

Description:

Main turbine master trip solenoid valves routine test Cause: N/A Effects: None Position Applicant's Actions or Behavior CRS Direct PRO to perform RT-O-01 0-402-2 "Master Trip Solenoid Valves Operability Test".

PRO Perform RT-O-01 0-402-2 "Master Trip Solenoid Valves Operability Test":

Review RT

Place the Master Trip Test Selector switch to TRIP A

Verify "Test A" lamp is OFF

Release and place Master Trip Test Selector switch to RESET

Verify "Test A" lamp is ON

Place the Master Trip Test Selector switch to TRIP 8

Verify 'Test 8" lamp is OFF

Release and place Master Trip Test Selector switch to RESET

Verify "Test 8" lamp is ON

Complete RT paperwork CRS Review RT for completeness/satisfactory results.

URO Monitor plant parameters/assist as directed.

2013 NRC Scenario #2 - T -103 HPCI Steam Leak, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 2 Page: 2of14 Event

Description:

Turbine stop valve fails closed I Reactor power reduction Cause: An internal fault in the control pac for #3 stop valve causes the stop valve to go closed Effects: 1. Alarms: 201 H-1 "Feedwater Field Instrument Trouble" 206 A-4 "Main Steam Line Bypass Valve Open"

2. Reactor pressure will rise due to the valve closure; reactor power will rise in response to the rise in reactor pressure, Bypass valve(s) will open.

Time Position Applicant's Actions or Behavior URO/PRO Recognize and report alarm 201 H-1 "Feedwater Field Instrument Trouble" and enter the corresponding Alarm Response Card.

Recognize and report alarm 206 A-4 "Main Steam Line Bypass Valve Open" Recognize and report main turbine bypass valve open Recognize and report the rise in reactor pressure.

Recognize and report entry into OT-1 02 "Reactor High Pressure".

Enter and execute OT-102 "Reactor High Pressure".

Recognize and report Load Limit light lit on main turbine Panel 20C008A.

Recognize closure of the #3 Main Turbine Stop Valve.

Request I&C assistance to respond to alarm 201 H-1 "Feedwater Field Instrument Trouble" URO/PRO Recognize and report the rise in reactor power.

(May) recognize and report entry into OT-104 "Positive Reactivity Insertion".

CRS Enter and execute OT-102 "Reactor High Pressure".

(May) enter and execute OT-104 "Positive Reactivity Insertion".

Exit OT-104 (per step 3.2).

Recognize OT-1 02 requirement to reduce reactor thermal power within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to comply with Tech Spec 3.2.

Enter and execute GP-5 "Power Operation" per OT-102, step 3.5.

Direct that an EO walkdown accessible areas of EHC system components searching for causal factors.

URO/PRO Direct Equipment Operator to walkdown accessible areas of EHC system components searching for causal factors.

2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev 1

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 2 Page: 30f14 Event

Description:

Turbine stop valve fails closed I Reactor power reduction (continued)

Position Applicant's Actions or Behavior CT CRS Direct the URO to lower reactor power to S95% (3338 MWth) per GP-5, step 6.,32.

Verify operation is within the acceptable region of AO 1E. 4-2 "Planned Removal of the Fifth or Fourth Stage Feedwater Heaters for Service During End of Cycle Coastdown and Return to Normal Shutdown Condition" .

CT URO Lower reactor power using Recirc until reactor power S95% (3338 MWth),

as directed.

PRO Recognize and report main turbine bypass valve open Recognize and report Load Limit light extinguished on main turbine Panel 20C008A NOTE: "Main Steam Line Hi Radiation" (218 0-2) may alarm and clear during the power reduction due to Hydrogen Water Chemistry injection.

2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 3 Page: 4of14 Event

Description:

'A' Recirc M-G Flow Controller oscillations Cause: Failure in the IN flow controller Effects: 1. Jet pump flow oscillation

2. Total flow oscillations

3. Reactor level oscillations

4. 'A' Recirc parameter changes

5. Reactor power oscillations Position Applicant's Actions or Behavior URO Recognize and report the 'A' Recirc pump (controller) oscillations Recognize and report the oscillations as an entry into OT-112 "Unexpected/Unexplained Change in Core Flow".

URO may lockup the lA' Recirc M-G set without direction at this time.

CRS Enter and execute OT-112 "Unexpected/Unexplained Change in Core Flow".

Plot conditions on the Power to Flow map

Direct monitoring for THI Direct the URO to Lock-up the 'A' Recirc pump by placing the Scoop Tube switch to "LOCK" at pane120C004A.

Refer to SO 20.7.8-2 "Recirculation MG Set Scoop Tube Lockup and Reset", especially for transient and scram actions for a locked up Recirc pump.

Verify the Jet pump flow mismatch is within:

10.25 Mlbm/hr IF total core flow < 71.75 Mlbm/hr

5.125 Mlbm/hr I F total core flow>71.75 Mlbm/hr Direct that reactor power be maintained.::: 95% based on Event 1.

(May) dispatch a licensed operator to manually operate the 'A' Recirc pump using AO 20.2-2 "Recirculation MG Set Scoop Tube Manual Operation" .

URO "Lock up" the 'A' Recirc MG Set if not already completed.

Monitor for THI 2013 NRC Scenario #2 T-I03 HPCI Steam Leak, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 4 Page: 50f14 Event

Description:

Inadvertent HPCI initiation Cause: Initiation relay contacts short closed Effects: 1. Alarms:

222 D-5 "HPCI Auxiliary Oil Pump Running"

228 C-5 "HPCI Relays Not Reset"

2. HPCI injection to the reactor; reactor water level and reactor power increase Position Applicant's Actions or Behavior PRO Recognize and report HPCI initiation.

Verify, using at least two independent indications, misoperation of HPCI and/or adequate core cooling is assured.

URO Recognize and report entry into OT-104 "Positive Reactivity Insertion" and OT-110 "Reactor High Level".

Control feed pump speed / discharge pressure as necessary to maintain reactor water level below +35 inches.

CRS Enter and execute OT-104 "Positive Reactivity Insertion".

Verify, using at least two independent indications, misoperation of HPCI and/or adequate core cooling is assured.

Direct HPCI short term shutdown in accordance with RRC 23.1-2 "HPCI System Operation during a Plant Event".

Enter and execute OT-110 "Reactor High Level".

Direct maintaining reactor water level below +35 inches.

Review Tech Spec 3.3.5.1 and determine Condition B applies:

Declare HPCI inoperable within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Place the channel in trip within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Review Tech Spec 3.5.1 and determine Condition C applies:

Verify RCIC operability immediately.

Restore HPCI to operable status within 14 days.

May reference GP-25 "Installation of Tripsllsolations to Satisfy Tech SpeclTRM Requirements for Inoperable Instrumentation.

Request Maintenance and/or I&C assistance in investigating cause of inadvertent HPCI initiation.

2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev 1

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 4 Page: 60f14 Event

Description:

Inadvertent HPCI initiation (continued)

Position Applicanfs Actions or Behavior PRO Perform RRC 23.1-2 uHPCI System Operation During a Plant Event",

Section E, "HPCI Shutdown With Initiation Signal Present (short-term shutdown):

Place Aux Oil Pump control switch in START.

Place Vacuum Pump control switch in START.

Depress and hold Remote Trip pushbutton.

When turbine speed reaches - 0 RPM, place Aux Oil Pump control switch in P-T-L and release the Remote Trip pushbutton.

CRS (May) direct PRO to follow-up with SO 23.2.A-2 "HPCI System Shutdown" PRO (May) perform SO 23.2.A-2 "HPCI System Shutdown" 2013 NRC Scenario #2 - T-\03 HPCI Steam Leak, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 5 Page: 7of14 Event

Description:

HPCI steam leak into Secondary Containment Cause: Unisolable HPCI steam line break in the HPCI room Effects: Secondary containment temperature will increase. First alarm to actuate is 210 J-3 "High Area Temp". This will cause an entry into T-103 "Secondary Containment Control".

Position Applicant's Actions or Behavior PRO/URO Recognize and report the "High Area Temp" alarm (210 J-3) and enter the correspond Alarm Response Card.

Recognize and report the Fire Panel alarm (007 0-6 Lower).

PRO Report the rise in HPCI room temperature (Point #3).

Report the temperature alarm as an entry into T -103 "Secondary Containment Control".

CRS Enter and direct T-103 "Secondary Containment Control".

Monitor and control secondary containment temperatures.

Perform a local evacuation lAW GP-15.

Direct operators to isolate HPCI.

Determine a primary system is discharging into the Reactor Building.

PRO Monitor secondary containment temperatures on TR-2-13-139.

Inform the CRS of the failure to isolate HPCI (see Event 6).

Perform a GP-15 local evacuation as directed.

2013 NRC Scenario #2 - T -103 HPCI Steam Leak, Rev I

Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 2 Event No.: 5 Page: 8of14 Event

Description:

HPCI steam leak into Secondary Containment (continued)

Position Applicant's Actions or Behavior CT CRS Direct a GP-4 "Manual Reactor Scram" before HPCI room temperature (Point #3) exceeds the action level of 150 degrees F.

Enter and direct T-101 "RPV Control".

CT URO Perform GP-4 "Manual Reactor Scram" as directed:

Place the mode switch to SHUTDOWN.

Verify control rods are inserting.

Verify APRMs are downscale.

When reactor level begins to recover, then "Emergency Stop" all 3 RFPTs.

Depress "SLOW RAISE" or "FAST RAISE" on the RFPT to remain in service.

Close all RFP discharge valves and open 'C' RFP discharge bypass valve. (See Event 8)

Establish and maintain reactor level control with feedwater.

Verify all control rods are inserted.

Verify reactor pressure, trend, and status of EHC.

Notify health physics of changing plant conditions.

PRO Perform GP-4 "Manual Reactor Scram" as directed:

Transfer 13 KV house loads.

Trip main turbine when less than 50 MWe.

Verify main generator lockout. (See Event 7)

Verify Group II and III isolations and SGTS initiation.

Verify scram discharge volume vents and drains are closed.

Verify hydrogen water chemistry is isolated.

Verify both recirc pumps speed have runback to 30%.

Monitor instrument air header pressure and drywell pressure.

When the eRS is ready, report scram actions.

2013 NRC Scenario #2 - T-I03 HPCI Steam Leak, Rev 1

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 5 Page: 90f14 Event

Description:

HPCI steam leak into Secondary Containment (continued)

Position Applicant's Actions or Behavior CRS Direct the URO to control reactor level between +5" to +35" with feedwater.

Direct the PRO to bypass and restore instrument nitrogen to the drywell.

lIRO Control reactor level between +5" to +35" with feedwater.

PRO Bypass and restore drywell instrument nitrogen lAW RRC 94.2-2 or GP-8E.

Place AO-2969A control switch to "CLOSE".

Place AO-2969B control switch to "CLOSE".

Place Dryweilinstrument Nitrogen Bypass Switch 16A-S100 in the "BYPASS" position.

Place Dryweilinstrument Nitrogen Bypass Switch 16A-S99 in the "BYPASS" position.

Place AO-2969A control switch to "OPEN".

Place AO-2969B control switch to "OPEN".

CRS Direct reactor depressurization to 500-600 psig lAW T-101 "RPV Control" URO/PRO Perform reactor depressurization to 500-600 psig using the Bypass Valves, as directed. (See Event 9) 2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 6 Page: 10 of 14 Event

Description:

HPCI Isolation Pushbutton and Control Switch Failure Cause: Logic and Control Switch failure Effects: HPCI will fail to isolate, resulting in Secondary containment temperature continuing to increase.

Position Applicant's Actions or Behavior PRO Attempt to isolate HPCI using the Isolation Pushbutton Recognize and report the failure of the MO-2-23-15 and -16 valves to fully close PRO Attempt to manually close the MO-15 and -16 valves.

Recognize and report the failure of the MO-15 and 16 valves to fully close 2013 NRC Scenario #2 - T -103 HPCI Steam Leak, Rev I

Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 2 Event No.: 7 Page: 11 of 14 Event

Description:

Generator lockout fails to occur following Main Turbine trip Cause: Failure in the generator lockout circuit Effects: Main Generator output breakers fail to open Main Generator exciter field breaker fails to open Position Applicant's Actions or Behavior PRO Recognize the failure of the Main Generator lockout while performing PRO scram actions.

Open the Main Generator output breakers (215 BKR and 225 BKR).

Open the exciter field breaker (ALT EXC FLO BKR 41-0601).

Report to the eRS that the Main Generator lockout failed and that you manually opened the Main Generator output breakers and the field breaker.

2013 NRC Scenario #2 - T-103 HPC I Steam Leak, Rev I

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 8 Page: 12 of 14 Event

Description:

'C' reactor feed pump discharge bypass valve fails to open Cause: Failure of the motor operator for MO-8090 eC' feed pump discharge bypass) to engage and open the valve Effects: Reactor level must be controlled using the RFP discharge valve and not the RFP bypass, complicating post-scram and post blowdown Reactor level control.

Position Applicant's Actions or Behavior URO Recognize the failure of MO-8090 to open during URO scram actions.

Throttle open RFP discharge valve MO-2149A, B or C.

Maintain reactor level by controlling RFP discharge valve position and RFP speed (pump discharge pressure).

NOTE: when RFP's are no longer available (e.g., following emergency depressurization), the RPF discharge valve must be throttled to control Condensate flow to the reactor.

2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev 1

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 9 Page: 13 of 14 Event

Description:

Bypass Valves Fail Closed Cause: EHC System failure Effects: Operator attempts to de-pressurize will require shifting over to using Safety Relief Valves.

Position Applicant's Actions or Behavior URO Open Bypass Valves to initiate depressurization to 500 to 600 psig as directed Recognize and report closure of Bypass valves 60 seconds after initial opening Attempt to re-establish control with Bypass valves Recognize and report inability to open Bypass valves CRS Direct URO to continue depressurization using Safety Relief Valves (May) Direct URO to establish Torus Cooling lAW RRC 10.1 "RHR System Torus Cooling during a Plant Event" CRS Continue depressurization using Safety Relief Valves Establish Torus Cooling lAW RRC 10.1.

2013 NRC Scenario #2 - T -103 H PCI Steam Leak, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 10 Page: 14 of 14 Event

Description:

Emergency blowdown due to exceeding Reactor Building temperature limits in more than one area Cause: Steam leak in the Reactor Building continues to degrade Secondary Containment parameters Effects: Reactor depressurization via ADS SRVs Position Applicant's Actions or Behavior CT CRS When the same parameter exceeds an action level in more than one area (HPCI Room and Torus Room) and the primary system breach has not been isolated, enter and execute T-112 "Emergency Blowdown":

Verify torus level is above 7 feet.

Verify reactor pressure is 50 psig or more above torus pressure.

Direct 5 ADS SRVs opened.

CT PRO When directed, open 5 ADS SRVs by placing their control switches in OPEN.

POST SCENARIO EMERGENCY CLASSIFICATION:

Classification is a Site Area Emergency lAW EAL FS1, Based on a Loss of the Primary Containment Barrier and a Loss of the Reactor Coolant System Barrier.

Based on the scenario conditions and expected outcome, the CRS should determine that there is a Release in Progress.

TERMINATION CRITERIA:

The scenario may be terminated when 5 SRVS are open, the reactor is depressurized, and reactor level is under control.

2013 NRC Scenario #2 - T-I03 HPC[ Steam Leak, Rev 1

Scenario Outline ES-D-l Simulation Facility Peach Bottom Scenario No. Op Test No. 2013 NRC Examiners Operators _ _ _ _ _ _ _ _ CRS (SRO)

_ _ _ _ _ _ _ _ URO (ATC)

_ _ _ _ _ _ _ _ PRO (BOP)

Scenario The scenario begins with the reactor at 100% power. After taking the shift the crew is required to Summary swap operating TBCCW pumps for inspection of a noisy bearing on the 'A' TBCCW pump.

Next, an individual control rod drive scram accumulator will experience low pressure and alarm in the main control room. The crew will initiate corrective action but the accumulator pressure will remain low requiring the crew to declare the control rod slow or inoperable per Technical Specifications.

Shortly after this, the E-4 diesel generator will inadvertently start, requiring the crew to shutdown the E-4 diesel generator and apply Technical Specifications for an inoperable diesel generator.

The crew should then recognize and respond to lowering main condenser vacuum caused by a failure of the in service steam jet air ejector steam supply valve. The crew must enter OT-106 "Condenser low Vacuum" and reduce reactor power in accordance with GP-9-2 "Fast Power Reduction".

Following the power reduction, a turbine lube oil malfunction will result in a high bearing temperature and vibration condition for the main turbine, requiring the crew to scram the reactor and trip the main turbine. A CRD hydraulic malfunction will result in a low-power ATWS, requiring the crew to execute T-101 "RPV Control" and T-117 "level/Power ControL" In addition, the scram discharge volume (SDV) will fail to completely isolate, requiring the crew to manually isolate the SDV.

When SBlC is initiated the SBlC pump will trip, requiring the URO to place the alternate SBlC pump in service. The second SBlC pump will trip shortly after being placed in service. A failure of the only available EHC pump will cause the turbine bypass valves to close, requiring the crew to utilize HPCI and/or SRVs for reactor pressure control. The crew should perform T -220 "Driving Control Rods During Failure to Scram" to insert control rods. The crew will need to adjust control rod drive water pressure in order to successfully insert the control rods. The scenario may be terminated when the crew has control of RPV power and level using T-240 "Termination and Prevention of Injection into the RPV" and the crew is inserting control rods.

Initial IC-120, 100% power i Conditions Turnover See Attached "Shift Turnover" Sheet Event Malfunction Event Event No. No. Type* Description 1 See Scenario Guide N PRO Swap operating TBCCW Pumps CRS 2 See Scenario Guide TS CRS Individual control rod drive scram accumulator low pressure (Tech Spec) 3 See Scenario Guide I PRO E4 diesel generator spurious start I diesel generator shutdown TS CRS (Tech Spec) 4 See Scenario Guide C PRO Failure of Steam Jet Air Ejector steam supply valve / re-open by placing additional valve air supply in service 2013 NRC Scenario #3 - T 117 Hydraulic ATWS, Rev 1

Even Event Event No. No. Type'" Description 5 See Scenario Guide R URO Fast reactor power reduction (wI recirc)

CRS 6 See Scenario Guide C URO Main turbine high temperature and vibration I reactor scram CRS 7 See Scenario Guide M ALL ATWS (hydraulic) I turbine bypass valves fail closed 8 See Scenario Guide C URO Standby liquid control (SBLC) pump trips / start second SBLC pump CRS /second pump trips 9 See Scenario Guide C PRO Two in-series scram discharge volume (SDV) vent valves fail to CRS automatically isolate 10 See Scenario Guide C URO Low CRD drive water pressure / adjust to drive control rods

(N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev 1

SIMULATOR OPERATOR INSTRUCTIONS FOR 2013 NRC SCENARIO #3 GENERAL REQUIREMENTS

Recorders will be rolled prior to the scenario and paper from selected recorders will be retained for the examination team as requested.

All procedures, flow charts, curves, graphs, etc. will be in their normal storage places.

All markable procedures, boards, etc. will be erased.

All paper used by the crew will be retained for the examination team as requested.

The simulator operators will keep a log of all communications during the scenario as requested by the examination team.

SCENARIO SOURCE HISTORY

This Scenario originated from the 2007 NRC Initial License Exam. It was significantly modified for the 2009 and 2010 CERT Exams. It has been altered here by replacing Event 1, adding new events 4 and 10, and deleting an event.

INITIAL SETUP Initial Conditions

IC-120, 100% power (created from IC-14)

Ensure recorder power is on; roll recorders as required

Ensure annunciator horns are active Blocking Tags

Apply Information Tag to the 2B EHC Pump control switch

Apply Information Tag to Annunciator 205 K-3 EHC STANDBY PUMP NOT IN AUTO Activate APP "2013_NRC_SCN3" or insert the following:

Event Triggers TRG E5 REACTOR_MODE_SWITCH_NOT_IN_RUN TRG E6 RPV_LEVEL_LE_-48 TRG E7 SBLC_SWITCH_IN_START-A TRG E8 SBLC_SWITCH_IN_START-B TRG E9 SDV_INBD_NOT_IN_AUTO TRG E10 SDV_OUTBD_NOT_IN_AUTO TRG E11 MO_3_20_CLOSE TRG =

E5 DMF IPM03 TRG E7 = DMF SLC01 B TRG E8 = DMF SLC01A TRG E9 = DMF CRH09B TRG E10 = DMF CRH09D TRG E11 = MMF CRH01A (none 20 0) 70 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev 1

Malfunctions IMF CRH098 (none 0 0) (inboard SDV vent valve fails to isolate)

IMF CRH09D (none 0 0) (outboard SDV vent valve fails to isolate)

IMF IPM03 (none 0 0) 8000 (hydraulic ATWS)

IMF SLC01A (none 0 0) (SBLC Pump A trip)

IMF SLC018 (none 0 0) (SBLC Pump B trip)

IMF CAR01 (E3 0 0) 2 0 0 (Main Condenser air in-leakage at 2% severity)

IMF MTA018 (E4 00) 100 10:00 0 (Main Turbine bearing 'B' high temperature)

IMF MTA028 (E4 00) 100 10:000 (Main Turbine bearing 'B' high vibration)

IMF MTA02C (E4 00) 100 10:000 (Main Turbine bearing 'C' high vibration)

IMF EHH04A (E6 2:00 0) (2A EHC pump trip ... 2 minutes after RPV level.::: -48 inches)

IMF EHH02A (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF EHH028 (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF EHH02C (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF EHH02D (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF EHH02E (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF EHH02F (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF EHH02G (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF EHH02H (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF EHH021 (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level.::: -48 inches)

IMF CRH01A (E8 0 0) 5 (CRD flow control valve fails to 5% open on start of B SBLC pump)

Overrides lOR ZLOTC08A28P17_1 (none 0 0) OFF (Block 2B EHC pump green light) lOR ZYP01A6S39 (none 0 0) STOP (Block 2B EHC pump control switch) lOR ZYP04A8S04 (E1 02) START (E-4 DG QUICK START pushbutton) lOR ZYP02A6S28 (E8 0 15) OPEN (MO-2-3-20 strokes open for 15 seconds after B SBLC pump is started) lOR ZYP02A6S27 (E8 16 2) THROTTLE (MO-2-3-20 open stroke is stopped 16 seconds after starting by depressing throttle pushbutton for 2 seconds)

Trip Overrides None Turnover Procedures None 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev 1

S/MULA TOR OPERATOR DIRECTIONS EVENT 1 Support crew for TBCCW pump swap in accordance with SO 34.6.A-2.

When directed, report Step 4.1 of SO 34.B.A-2 is complete.

When directed per Step 4.2.1 of SO 34.B.A-2, report 'B' TBCCW pump discharge pressure is 85 psig.

When directed per Step 4.4 of SO 34.6.A-2, report '8' TBCCW pump discharge pressure is 85 psig.

EVENT 2 After the swap of TBCCW pumps, initiate ET2 (IMF CRH051423) to cause a low HCU accumulator alarm condition for control rod 14-23.

When directed to go to the HCU for rod 14-23 per ARC 211 E-2, WAIT 2 minutes and report an unisolable leak on the accumulator and pressure is 900 psig and slowly lowering.

EVENT 3 After the Tech Spec determination is competed, or when directed by the Lead Examiner, initiate ET1 (lOR ZYP04A8S04 START) to cause a spurious start of diesel generator E4.

After the E4 diesel starts, verify override ZYP04A8S04 is deleted.

If directed to perform running inspection of E4 EDG, report as the Equipment Operator the E4 diesel unning inspection is complete and everything appears normal.

IF EO is NOT dispatched to EDG, report as I&C I Maintenance person in the EDG room that the EDG is running normally.

Support shutdown of EDG per SO 52A.1.B "Diesel Generator Operations".

EVENTS 4 & 5 After the TS requirements have been determined for the EDG spurious start, or when directed by the Lead Examiner, insert Remote Function IRF MSS05A 'A' SJAE Steam Isolation Valve AO-2466A CLOSE to close AO-2466A and initiate a main condenser low vacuum condition.

Support the crew for GP-9, "Fast Power Reduction". Role-playas the Power System Director when called.

IF the Lead Examiner requires additional GP-9 power reduction, initiate ET3 (IMF CAR01 2 0 0) to cause Main Condenser air in-leakage at 2% severity. (NOTE: With NO power reduction, appox 2 minutes to Cond Lo Vac alarm.) THEN MMF CAR01 1 1:000 to reduce the severity of the condenser in-leakage to 1% severity. AFTER GP-9 is intiated. DMF CAR01 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev 1

SIMULA TOR OPERATOR DIRECTIONS EVENT 6 After power is reduced, or as directed by the Lead Examiner, initiate ET4 and verify the following malfunctions:

IMF MTA018 100 10:00, "Main Turbine Bearing B High Temperature."

IMF MTA028 100 10:00, "Main Turbine Bearing B High Vibration."

IMF MTA02C 100 10:00, "Main Turbine Bearing C High Vibration."

EVENT 7 If directed to investigate the main turbine, wait 5 minutes and when bearing #2 is above 225 degrees F (PMS shortcut uTG8"), report there is no oil flow to #2 bearing.

When the mode switch is placed in SHUTDOWN (Le., not in RUN), verify trigger ET5 (DMF IPM03) deletes the ATWS malfunction.

When RPV level is lowered to -50 inches, verify trigger ET6 (IMF EHH04A) initiates a trip of the 'A' EHC pump 2 minutes later.

When requested to perform T-221 , wait 5 minutes then MRF T221_1 DEFEAT "Remove Low RPV LeveI/GP1lsolation".

After 5 minutes report to the MeR by phone that T-221 jumpers (step 4.1) have been installed.

When requested as the Equipment Operator to perform T-216 steps 4.1 and 4.2, acknowledge direction but DO NOT COMPLETE THE TASK.

EVENT 8 Pre-inserted malfunctions will trip the 'A' or 'B' Standby Liquid Control pump; whichever one is placed in service first. When the 'A' or 'B' SLC pump is started, VERIFY the trip malfunction for the other pump is deleted:

TRG E7 = DMF SLC018 (if the 'A' SLC pump was placed in service)

TRG E8 = DMF SLC01A (if the 'B' SLC pump was placed in service)

When the B SLC Pump is started verify the following override initiates:

lOR ZYP02A6S28 (E8 015) OPEN (opens MO-2-3-20 for 15 seconds after B SLC pump is started to lower CRD drive water pressure)

lOR ZYP02A6S27 (E816 2) THROTTLE (stops the open stroke for MO-2 3-2016 seconds into its open stroke)

IMF CRH01A (E8 0 0) 5 (CRD flow control valve fails to 5% open on start of B SBLC pump)

One minute after the standby SLC pump is started, trip the pump by inserting malfunction IMF SLC01A or SCL01 B (trip of A or B SLC pump) 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev I

SIMULATOR OPERATOR DIRECTIONS EVENT 9 Two SDV vent valves (AO-0328 and AO-0358) fail to automatically isolate on the scram - pre-inserted.

When the crew manually isolates the SDV vent valves, verify the following:

TRG E9 =DMF CRH09B

TRG E10 =DMF CRH09D EVENT 10 IF the operator strokes closed MO-2-3-20 to raise CRD drive water pressure, verify initiation of MMF CRH01A (none 20 0) 70 (repositions CRD flow control valve to 70% open on a 20 second delay)

TERMINATION The scenario may be terminated when the crew has control of RPV power and level using T-240 'Termination and Prevention of Injection into the RPV" and the crew begins inserting control rods per T -220.

2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev 1

SHIFT TURNOVER PLANT CONDITIONS:

Unit 2 is at 100% power INOPERABLE EQUIPMENT/LCOs:

2B EHC pump is blocked OOS for micron filter replacement SCHEDULED EVOLUTIONS:

Swap running TBCCW Pumps per SO 34.6.A-2. Noisy bearing on the 'A' TBCCW pump motor; maintenance to install monitoring instrumentation.

SURVEILLANCES DUE THIS SHIFT:

None ACTIVE CLEARANCES:

2B EHC pump GENERAL INFORMATION:

None 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev 1

CRITICAL TASK LIST

1. Before torus temperature exceeds the limits of the Heat Capacity Temperature limit (HCTl) curve, lower reactor power by performing T-240 "Terminating and Preventing Injection" to lower RPV level until:

a. Reactor power is below 4%, OR

b. RPV level reaches -172 inches, OR

c. All SRVs remain closed and drywell pressure is below 2 psig.

2. Initiate a reactor shutdown by inserting control rods in accordance with T-220 "Driving Control Rods During Failure to Scram" and/or shutdown the reactor by initiating Standby liquid Control before torus temperature exceeds the limits of the Heat Capacity Temperature limit (HCTl) curve.

2013 NRC Scenario #3 - T-J 17 Hydraulic ATWS, Rev I

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 3 Event No.: 1 Page: 1 of 13 Event

Description:

Swap TBCCW pumps Cause: Noisy bearing on the 'A' TBCCW pump motor; maintenance to install monitoring instrumentation Effects: N/A Position Applicant's Actions or Behavior CRS Direct the PRO to perform SO 34.6.A-2 "Placing the Standby Turbine Building Closed Cooling Water System Pump in Service."

PRO Perform SO 34.6.A-2 "Placing the Standby Turbine Building Closed Cooling Water System Pump in Service."

Contact the Equipment Operator to perform SO 34.6.A-2 Step 4.1 to vent the 'B' TBCCW pump and verify it ready for start NOTE: MCR TBCCW discharge pressure indication reads lower than local indication.

Start the 'B' TBCCW pump and direct the EO to verify discharge pressure is greater than 70 psig on local pressure indicator.

Stop the 'A' TBCCW pump and place it in AUTO.

Direct the EO to verify discharge pressure of running pump is greater than 70 psig and less than or equal to 87 psig on local pressure indicator.

Inform the CRS and Maintenance the pump swap is complete.

URO Monitor plant parameters and assist as directed.

2013 NRC Scenario #3 - T-II7 Hydraulic ATWS, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 2 Page: 2 of 13 Event

Description:

Individual control rod drive scram accumulator low pressure Cause: Leaking CRD HCU accumulator Effects: 1. Alarms:

211 E-2 "CRD Accum Lo Pres I Hi Level"

2. Control rod must be declared SLOW or INOPERABLE per Tech Spec.

Time Position Applicant's Actions or Behavior URO Acknowledge and report alarm 211 E-2 "CRD Accum Lo Pres I Hi Level" Recognize alarm condition is for control rod 14-23.

Reference the corresponding Alarm Response Card.

CRS Reference Alarm Response Card 211 E-2 "CRD Accum Lo Pres I Hi Level".

Direct that an Equipment Operator is dispatched to HCU 14-23.

URO Dispatch an Equipment Operator to HCU 14-23 CRS Upon field report of leaking HCU accumulator, references Tech Spec 3.1.5 for control rod scram accumulators.

Recognizes Tech Spec 3.1.5 Condition A applies.

Declare control rod 14-23 SLOW or INOPERABLE within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 3 Page: 30f13 Event

Description:

E4 diesel generator spurious start Cause: Spurious automatic start signal Effects: 3. Alarms:

005 F-4 "E4 Diesel Running"

002 A-5 "Emergency Service Water Pump Auto Start"

212 B-2 "Emergency Cooling Water Pump Auto Start"

4. The diesel will continue to run until manually shutdown ... it should not be left running for long periods unloaded due to accumulation of oil in the exhaust manifold.

Position Applicant's Actions or Behavior PRO Acknowledge and report alarm 005 F-4 "E4 Diesel Running" and enter corresponding Alarm Response Card.

Red flag the E4 Diesel Generator control Switch by placing the control Switch to "START" Recognize the E4 diesel is running unloaded.

Verify diesel automatic response using SO 528.1.B "Diesel Generator Automatic Start".

Verify an ESW pump started.

o Check pump discharge pressure (PI-0236A (B)) "DISCH PRESS" 25 to 64 psig.

o Check pump motor current "AMPS" 25 to 35 amps.

Red-flag the ESW pump to remain in service.

Shutdown the remaining ESW pump per ARC-002 A-5.

Direct an Equipment Operator to perform a running inspection of the E-4 diesel generator.

NOTE: the Lead Examiner, acting as the Shift Manager, may prompt the CRS to remove the E-4 diesel generator from service (do NOT perform a 2-hour load run).

CRS Per SO 52B.1. B (step 4.7), direct a shutdown of the E-4 diesel generator lAW the applicable steps of section 4.5 of SO 52A.1.B "Diesel Generator Operations".

(May) direct placing the E4 diesel in Pull-to-Lock.

Request Maintenance and/or I&C assistance in troubleshooting E4 diesel generator spurious start.

2013 NRC Scenario #3 - T -117 Hydraulic ATWS, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 3 Page: 4 of 13 Event

Description:

E4 diesel generator spurious start (continued)

Position Applicant's Actions or Behavior PRO Shutdown the E4 diesel lAW SO 52A.1.B:

Place the E4 diesel generator control switch to "STOP".

Shutdown the running ESW pump in accordance with SO 33.2.A.

Direct the Equipment Operator to continue with the E4 diesel shutdown in accordance with SO 52A.1.B, section 4.5.

Place the E4 diesel in Pull-to-Lock, as directed.

CRS Declare the E-4 diesel inoperable.

Review Tech Spec 3.8.1 and determine Condition B applies:

Verify alignment/availability of the Conowingo tie line immediately.

Verify breaker alignment for operable offsite circuits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Restore the E-4 diesel generator to operable status within 14 days.

2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 4&5 Page: 5 of 13 Event

Description:

Failure of Steam Jet Air Ejector steam supply valve I fast reactor power reduction Cause: leak in normal air supply to steam supply valve Effects: 1. Alarms:

201 H-3, "HWC System Trouble"

201 J-3, "HWC System Trip"

204 D-5, "SJAE Disch Hi/lo Press"

PMS Major: Off Gas Flow

2. GP-9 "Fast Power Reduction" required due to degraded main condenser vacuum Position Applicant's Actions or Behavior URO/PRO Acknowledge and report alarms:

201 H-3, "HWC System Trouble"

201 J-3, "HWC System Trip"

204 D-5, "SJAE Disch Hi/lo Press" Recognize and report A SJAE steam supply isolation valve AO-2466A closed on Panel 20C006B.

Recognize and report lowering main condenser vacuum.

CREW Enter and execute OT-106 "Condenser low Vacuum" URO Reduce reactor power in accordance with GP-9-2 "Fast Power Reduction" until vacuum stops lowering.

Lower recirculation flow as required to a value of no lower than 61.5 Mlbs/hr.

Stop power reduction when main condenser vacuum stops lowering andlor begins to improve.

CRS Recognize that step 3.B of OT-106 applies to present condition (AO 2466A closed)

Directs PRO to perform step 3.B of OT-106.

PRO Place control switch "A It Instr Air AO-2-0BA-2466A" to OPEN on Panel 20C007A.

Verify AO-2-0BA-2466A indicates open at Panel 20C006B.

Place PIC-2239A "A Steam Press" in MANUAL on Pane120C007A.

Restore SJAE steam supply pressure to between 115 and 125 psig.

2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 6 Page: 6of13 Event

Description:

Main turbine high temperature and vibration I reactor scram Cause: Lack of lube oil flow to the #2 main turbine bearing Effects: 1. Initial Alarms:

Alarm 205 H-4, "Turbine Bearing Metal Hi Temp"

Alarm 205 A-2, "Turbine Vibration I Thrust High"

2. Turbine bearing temperature and vibrations will rise. With no operator action, the main turbine will (eventually) automatically trip.

Position Applicant's Actions or Behavior URO/PRO Recognize and report alarm 205 H-4, 'Turbine Bearing Metal Hi Temp" and enter corresponding Alarm Response Card.

Identify affected bearing on temperature recorder TR-2401.

Check turbine lube oil temperature on TR-2401, and increase cooling water to lube oil coolers, if necessary.

Check vibration of the affected bearing on VR-2657.

Dispatch operator to check for proper oil flow and local temperature at the affected bearing.

CRS Direct operator actions lAW ARC 205 H-4, "Turbine Bearing Metal Hi Temp" and 205 A-2, "Turbine VibrationlThrust High".

Direct the reduction of turbine load lAW GP-9-2, "Fast Power Reduction" (the CRS may go directly to GP-4 "Manual Reactor Scram").

URO Perform a GP-9-2 "Fast Power Reduction" as directed.

CRS When bearing metal temperature increases to 250 degrees F, then direct a manual scram lAW GP-4 "Manual Reactor Scram" then direct the PRO to trip the Main Turbine (see next event).

PRO When directed by the CRS, or when bearing metal temperatures exceed 250 degrees F, then trip the Main Turbine.

2013 NRC Scenario #3 - T -1 17 Hydraul ic A TWS, Rev 1

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 3 Event No.: 7 Page: 7of13 Event

Description:

A TWS - hydraulic / turbine bypass valves fail closed Cause: Control rods insert to various positions due to limited Scram Discharge Volume Effects: Requires the crew to take actions to terminate the ATWS, as well as control RPV level/power Position Applicant's Actions or Behavior URO Perform GP-4 "Manual Reactor Scram":

Reduce recirc flow controllers to minimum (20% demand)

Place the mode switch to "SHUTDOWN".

Verify control rods are inserting.

Report APRMs are NOT downscale and that an ATWS is in progress with reactor power> 4% (T-101 entry condition).

Depress manual scram pushbuttons on Panel 20C005A.

PRO Perform GP-4 "Manual Reactor Scram":

Transfer 13 KV house loads using RRC 53.1-2.

CRS Enter/direct actions for T-101 "RPV Control":

Verify URO/PRO scram actions.

Direct tripping of the Main Turbine.

Direct RPV pressure stabilized below 1050 psig using BPVs, SRVs and/or HPCI.

Direct drywell instrument nitrogen restored.

Direct actions for the ATWS (see later in this event).

2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev I

Operator Actions Op Test No.: 1 Scenario No.: 3 Event No.: 7 Page: 8 of 13 Event

Description:

ATWS - hydraulic / turbine bypass valves fail closed (continued)

Position Applicant's Actions or Behavior PRO Trip the Main Turbine by depressing the "TRIP" pushbutton.

Stabilize reactor pressure below 1050 psig as directed using HPCI and/or SRVs.

When the isolation occurs (+1 inch RPV level):

Verify Group" & III isolations and SGTS initiation.

Verify HWC isolated.

Bypass and restore drywell instrument nitrogen lAW RRC 94.2-2 or GP-8E.

Place AO-2969A control switch to "CLOSE".

Place AO-2969B control switch to "CLOSE".

Place Drywell Instrument Nitrogen Bypass Switch 16A-S 100 in the "BYPASS" position.

Place Drywell Instrument Nitrogen Bypass Switch 16A-S99 in the "BYPASS" position.

Place AO-2969A control switch to "OPEN".

Place AO-2969B control switch to "OPEN".

NOTE: this activity may be coordinated between the URO and the PRO.

CRS Direct T-101! RC/Q ATWS actions:

Initiation of ARI

Trip recirc pumps at least 10 seconds apart CT

T-220 "Driving Control Rods During Failure To Scram"

T-216 "Control Rod Insertion by Manual Scram or Individual Scram Test Switches" CT

Enter T-117 "Level/Power Control"

SLC injection URO Perform T-101! RC/Q actions:

Initiate ARI using RRC 3B.1-2, "ARI During a Plant Event"; report the scram air header is depressurized.

Trip Recirc pumps at least 10 seconds apart.

Initiate SLC by starting either SLC pump (see Event #8).

Direct an Equipment Operator to perform T -216 steps 4.1 and 4.2 (install jumpers in Cable Spreading Room and Main Control Room to defeat ARI Initiation Logic and bypass all RPS Auto Scram signals).

CT

Perform T-220 "Driving Control Rods During Failure To Scram" (see Event #10).

2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 7 Page: 90f13 Event

Description:

ATWS - hydraulic / turbine bypass valves fail closed (continued)

Time Position Applicant's Actions or Behavior CRS Direct T-117 actions:

Inhibit ADS.

T-221 "Main Steam Isolation Valve Bypass".

CT

T-240 "Termination And Prevention Of Injection Into The RPV" per Attachment 1 Figure 1 OR

T -240 per Attachment 1 Figure 2 if:

o RPV level is > -172" and, o Reactor power is> 4% and, o An SRV is open and Drywell pressure> 2 psig and, o Torus temperature is > 110 0 F URO/PRO Perform T-117 actions:

Inhibit ADS per RRC 1G.1-2 "ADS Inhibit".

Direct 3rd Reactor Operator (via phone or radio) to perform T-221.

CT

Perform T-240: terminate and prevent injection from all injection sources except RCIC, SLC and CRD; control RPV level below -60 inches and within the specific RPV level band directed by the CRS.

o Place HPCI Aux Oil Pump in the "Pull-to-Lock" position.

o Press "Emergency Stop" for all reactor feed pumps.

o Close reactor feed pump discharge valves MO-2149A, 8, C.

o Verify closed MO-8090 "C RFP Discharge Bypass".

2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 7 Page: 10 of 13 Event

Description:

ATWS - hydraulic I turbine bypass valves fail closed (continued)

Time Position Applicant's Actions or Behavior UROJPRO When RPV level is below -60 inches, restore injection and maintain RPV level between -60 and -195 inches as follows:

Using Feedwater:

CT o Place LlC-8091 in "MAN" and close the valve.

o Open MO-8090 "C RFP Bypass".

o Raise RFP speed until discharge pressure is75-100 psig above RPV pressure.

o Control RPV injection by adjusting RFPT speed, OR LlC8091 setting, OR MO-2149C "RFP C Discharge" valve position.

Using HPCI (manual initiation):

o Arm and depress the "HPCI Manual Initiation" pushbutton.

c Verify MO-2-23-014 "Supply" opens.

c Verify the aux oil pump starts.

c Verify MO-2-23-019 "To Feed Line" opens.

c Verify vacuum pump starts.

c Verify AO-2-23-042 and AO-2-23-043 "Drain Isol to Mn Cndr" close.

o Adjust HPCI flow controller setpoint to the desired RPV injection rate.

URO/PRO Recognize loss of only available EHC Pump.

Recognize complete loss of EHC System and eventual loss of turbine bypass valves for RPV pressure control.

CRS Direct RPV pressure control using SRVs and/or HPCI.

URO/PRO Control RPV pressure using SRVs and/or HPCI to stay below 1050 psig, OR to stay on safe side of T-102 Curve T/L-1 "SRV Tail Pipe Limit", as applicable.

URO/PRO Place Torus cooling in service using RRC 10.1-2

Open MO-2-10-39A(B)

Open MO-2-32-89A (B, C, or D)

Start a HPSW Pump

Start an RHR Pump

Open MO-2-10-34A(B)

Place additional pumps in service as required

Direct an Equipment Operator to close stay full injection valve(s) for the RHR loop(s) in service 2013 NRC Scenario #3 - T-I17 Hydraulic ATWS, Rev I

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 8 Page: 11 of 13 Event

Description:

Both standby liquid control (SLC) pumps trip Cause: First SLC pump placed into service trips immediately on overcurrent Second SLC pump trips on overcurrent approximately 1 minute after being placed in service Effects: SLC system will not be available to mitigate the effects of the A TWS. Reactor power must be reduced using T-240, "Termination And Prevention Of Injection Into The RPV' and T-220, "Driving Control Rods During Failure To Scram".

Position Applicant's Actions or Behavior URO Recognize the Standby Liquid Control (SLC) pump placed into service has failed to start (pump immediately trips).

Place the standby SLC pump in service using keylock control switch on the 20C005A panel.

Recognize that the standby SLC pump also tripped approx. 1 minute after being placed in service.

CRS Acknowledge SLC pump failure to start.

Direct placing the backup SLC pump in service, if not already done.

Acknowledge standby SLC pump trip.

2013 NRC Scenario #3 T -117 Hydraulic ATWS, Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 9 Page: 12 of 13 Event

Description:

Two in-series scram discharge volume (SDV) vent valves fail to automatically isolate Cause: RPS failure in conjunction with an air header malfunction, which prevents air from venting off two SDV vent valves (common air supply).

Effects: A failure of the SDV vent valves is effectively a primary to secondary containment leak.

This requires manual isolation of the SOV vent valves.

Time Position Applicant's Actions or Behavior PRO Recognize and report failure of two SOV vent valves (AO-0328 and AO 0358) to automatically isolate.

Upon recognizing failure to isolate, the PRO should:

Manually isolate the valves by moving the SDV isolation hand switches counter-clockwise to the "Close" position.

Verify all vent and drain valves are closed.

Inform the CRS as conditions permit.

CRS Acknowledge SOV vent valve isolation failure.

Direct manual isolation of the SDV vent valves, if not already isolated.

NOTE: if the PRO scram actions (RRC 94.2-2) are not performed, or are delayed significantly, the SOV vent valve failure will result in T-103 and T-104 entry conditions, complicating this scenario.

2013 NRC Scenario #3 T-117 Hydraulic ATWS. Rev 1

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 10 Page: 13 of 13 Event

Description:

Low CRD drive water pressure Cause: Blockage in the CRD hydraulic system Effects: Low pressure will prevent control rods from being inserted manually per T-220. The operator must manually adjust (close) drive water pressure control valve MO-2-3-20 in order to insert control rods.

Position Applicant's Actions or Behavior URO Perform T-220 "Driving Control Rods During Failure To Scram"

Place FC-2-03-301 "CRD Flow Control" in MANUAL and open AO-2-3-19A "CRD Hydraulic System Flow Control" at Panel 20C005A.

Bypass the RWM (needs key inserted below RWM scsreen)

Attempt to insert control rods using the "Emergency In INotch Override" control switch on Panel 20C005A.

Recognize and report that control rods cannot be inserted due to drive water pressure being too low Raise CRD drive pressure by throttling closed MO-2-3-20 "Drive Water Pressure" at Panel 20C005A.

Insert control rods using the "Emergency In INotch Override" control switch on Panel 20C005A CRS Acknowledge report that control rods cannot be inserted due to drive water pressure being too low Direct closing of MO-2-3-20 if not already performed.

POST SCENARIO EMERGENCY CLASSIFICATION:

Classification is a Site Area Emergency lAW EAL MS2 (Scram condition >4% power with ARI not successful).

TERMINATION CRITERIA:

The scenario may be terminated when the crew has control of RPV power and level using T -240 "Termination and Prevention of Injection into the RPV" and the crew begins inserting control rods using T-220.

2013 NRC Scenario #3 - T-117 Hydrau 1ic ATWS, Rev 1

v t e Letter Sequence Other
TAC:U01867, (Open)
Initiation Acceptance... Administration Questions Answers Results Approval... Other: ML13098A252, ML13098A256, ML13098A262, ML13098A271, ML13182A574
MONTHYEAR2013-03-06 [Table View]

ML13098A271

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