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Signature / Title                Date S ig nature / Title Sig                              Date Signature / Title                Date APPROVED FOR USE:
Signature / Title                Date S ig nature / Title Sig                              Date Signature / Title                Date APPROVED FOR USE:
EFFECTIVE DATE: _ _      _----',_
EFFECTIVE DATE: _ _      _----',_
                                                          .----:'_ _ _,_ _.,_ __
__
NAME:                                                        ISSUE DATE:
NAME:                                                        ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
Line 129: Line 127:
: 1. In accordance with Technical Specification 3.1.4, specific combinations      "slow" control rods require a plant shutdown.
: 1. In accordance with Technical Specification 3.1.4, specific combinations      "slow" control rods require a plant shutdown.
The intent of the following step is to ensure any temperature corre    on for a control rod that has the POTENTIAL to require a plant shutdown is verified since a plant shutdown either will be, or will not be, performed based on the calculation.
The intent of the following step is to ensure any temperature corre    on for a control rod that has the POTENTIAL to require a plant shutdown is verified since a plant shutdown either will be, or will not be, performed based on the calculation.
: 2. The following step is not          ended to rest      performance of a plant
: 2. The following step is not          ended to rest      performance of a plant shutdown      required by Technical Specification 3.1.4.
      ,
shutdown      required
                          ..
by Technical Specification 3.1.4.
ANSWER KEY - DO NOT HAND OUT TO CANDIDATE
ANSWER KEY - DO NOT HAND OUT TO CANDIDATE


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Signature I Title        Date Signature I Title        Date Signature I Title        Date APPROVED FOR USE:
Signature I Title        Date Signature I Title        Date Signature I Title        Date APPROVED FOR USE:
I Title EFFECTIVE DATE: _ _ _        _,_ ,_ _ _    _,_
I Title EFFECTIVE DATE: _ _ _        _,_ ,_ _ _    _,_
                                                                      ,_ _
___
NAME:                                                    ISSUE DATE:
NAME:                                                    ISSUE DATE:
Last              First            M.1.
Last              First            M.1.
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Signature I Title      Date Signature I Title      Date APPROVED FOR USE:
Signature I Title      Date Signature I Title      Date APPROVED FOR USE:
Signature I Title      Date EFFECTIVE DATE: _ _              ,-_----:'---
Signature I Title      Date EFFECTIVE DATE: _ _              ,-_----:'---
                                                          '--_.'--
NAME:                                                    ISSUE DATE:
NAME:                                                    ISSUE DATE:
Last              First            M.1.
Last              First            M.1.
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[ 1  ENE                        1 SSE                  [  1  WSW AND The utility recommends that gove          ent officials notify the    eral public to take potassium iodide en            (KI) for those sectors where shelter is                          advise remainder of the EPZ to monitor c..
[ 1  ENE                        1 SSE                  [  1  WSW AND The utility recommends that gove          ent officials notify the    eral public to take potassium iodide en            (KI) for those sectors where shelter is                          advise remainder of the EPZ to monitor c..
   <C            EAS Messages.
   <C            EAS Messages.
m
m c..
  -
c..
en
en
(!)
(!)
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: 7. UTILITY PROTECTIVE ACTION RECOMMENDATION.: (a or b) - No action should be taken until government officials have been notified: by State:
: 7. UTILITY PROTECTIVE ACTION RECOMMENDATION.: (a or b) - No action should be taken until government officials have been notified: by State:
[X ] a NOT APPLICABLE (Unusual Event, Alert, Site Area Emergency, Tennination or Recovery only)
[X ] a NOT APPLICABLE (Unusual Event, Alert, Site Area Emergency, Tennination or Recovery only)
- ---(Complete
- ---(Complete the fol/owing for Shelter or Evacuation for a General Emergency only for the applicable station):
            - ._- - - - - - - -        - ---      - ---------                - -------            --    -------
the fol/owing for Shelter or Evacuation for a General Emergency only for the applicable station):
 
1b. The PROTECTIVE ACTION RECOMMENDATION (PAR) from the utility is:
1b. The PROTECTIVE ACTION RECOMMENDATION (PAR) from the utility is:
SHELTER 360 DEGREES FROM 0 MILES (SITE BOUNDARY) TO _ _ _                          _._._
SHELTER 360 DEGREES FROM 0 MILES (SITE BOUNDARY) TO _ _ _                          _._._
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[  ] ENE                        ]                      [ ]  WSW AND The utility recommends that 9                                                    to take potassium iodide en            (KI) for those sectors where shelter                                                of the EPZ to monitor 0
[  ] ENE                        ]                      [ ]  WSW AND The utility recommends that 9                                                    to take potassium iodide en            (KI) for those sectors where shelter                                                of the EPZ to monitor 0
0-ct            EAS Messages.
0-ct            EAS Messages.
    -
m 0
m 0
0-en
0-en
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Signature I Tille              Date Signature I Title              Date Signature APPROVED FOR USE:
Signature I Tille              Date Signature I Title              Date Signature APPROVED FOR USE:
EFFECTIVE DATE: _ _      _---',_
EFFECTIVE DATE: _ _      _---',_
                                                        ---',_ _    _-----:'_
                                                                      -----:'_ _
___
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
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(Step 4.1)    Unit:      3 Associated control rod:                18-55        VfR,O !loaay Record the CRD Temperature:                          VfR,O !loaay Position 46 Scram Time Penalt          Calculat (Step 4.2)  Posit      46 Scram Time:            0.343 sec        VfR,O !loaay (St  4.3 ) Position 46 Penalty (from Table 1    low) :                          0.35  sec      VfR,O !loaay (Step 4.4) Determine the              rature Corrected Position 46 Control Rod Scram Time by adding the Position 46 Scram Time and Position 46 Penalty:                      0.693 sec        VfR,O !loaay (Step 4.5) Maximum Notch Position 46 Scram Time allowed by Tech Spec Table 3.1.4 1:                          0.44  sec      VfR,O !loaay Table 1: GE SIL 173 Position 46 Penalty 1
(Step 4.1)    Unit:      3 Associated control rod:                18-55        VfR,O !loaay Record the CRD Temperature:                          VfR,O !loaay Position 46 Scram Time Penalt          Calculat (Step 4.2)  Posit      46 Scram Time:            0.343 sec        VfR,O !loaay (St  4.3 ) Position 46 Penalty (from Table 1    low) :                          0.35  sec      VfR,O !loaay (Step 4.4) Determine the              rature Corrected Position 46 Control Rod Scram Time by adding the Position 46 Scram Time and Position 46 Penalty:                      0.693 sec        VfR,O !loaay (Step 4.5) Maximum Notch Position 46 Scram Time allowed by Tech Spec Table 3.1.4 1:                          0.44  sec      VfR,O !loaay Table 1: GE SIL 173 Position 46 Penalty 1
CRD Temp            Pos ion 46 Penalty
CRD Temp            Pos ion 46 Penalty
                     > 350 0 F and < 400 0 F      0.07 sec
                     > 350 0 F and < 400 0 F      0.07 sec 400 0 F            0.35 sec (Step 4.6) Pos ion 46 temperature corrected Control Rod Scram Time Independent Veri              ion    rmed by:        111lL/I'otfay
                            ->
400 0 F            0.35 sec (Step 4.6) Pos ion 46 temperature corrected Control Rod Scram Time Independent Veri              ion    rmed by:        111lL/I'otfay
: 1. V.
: 1. V.


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                     -> 350 0 F and < 400 0 F        0.14 sec
                     -> 350 0 F and < 400 0 F        0.14 sec
                               > 400 0 F
                               > 400 0 F
                              -
                                                 !  0.60 sec (Step 4.6) Position 36 temperature corrected Control Rod Scram T      Independent Verification performed by:          I1Jq(JI'otfay I.V.
                                                 !  0.60 sec (Step 4.6) Position 36 temperature corrected Control Rod Scram T      Independent Verification performed by:          I1Jq(JI'otfay I.V.


AO 3.8 Rev. 0 Page 8 of 9 :          Control Rod Scram Time          ct Calculation Initial Date (S        4.1)    Unit:      3 Associated control rod:                18 55      ViP lToaay Position 26 Scram Time Penalt                    tion
AO 3.8 Rev. 0 Page 8 of 9 :          Control Rod Scram Time          ct Calculation Initial Date (S        4.1)    Unit:      3 Associated control rod:                18 55      ViP lToaay Position 26 Scram Time Penalt                    tion
( S t e p 4. 2 )  Po sit ion 2 6 SScram cram              1.396    sec    ViP lToaay (Step 4.3)        Position 26 Penalty (from Table 3 below):                                  0.70    sec    ViP lToaay (Step 4.4) Determine the Temperature Correct          Pos ion 26 Control Rod Scram Time by adding t            Posit      26 Scram and Position 26 Penalty:                      2.096 sec      ViP lToaay (Step 4.5) Maximum Notch Pos              ion 26 Scram Time allowed by Tech Spec Table 3.1.4-1:                                1. 83  sec      ViP lToaay Table 3: GE SIL 173 Position 26 Penalty CRD Temp          Position 26 Penalty
( S t e p 4. 2 )  Po sit ion 2 6 SScram cram              1.396    sec    ViP lToaay (Step 4.3)        Position 26 Penalty (from Table 3 below):                                  0.70    sec    ViP lToaay (Step 4.4) Determine the Temperature Correct          Pos ion 26 Control Rod Scram Time by adding t            Posit      26 Scram and Position 26 Penalty:                      2.096 sec      ViP lToaay (Step 4.5) Maximum Notch Pos              ion 26 Scram Time allowed by Tech Spec Table 3.1.4-1:                                1. 83  sec      ViP lToaay Table 3: GE SIL 173 Position 26 Penalty CRD Temp          Position 26 Penalty 350 0 F and < 400 0 F      0.17 sec
                          ->
350 0 F and < 400 0 F      0.17 sec
                                   > 400 0 F            0.70 sec (S        4.6)    Position 26 temperature corrected Control Rod Scram              Independent Verification performed by:            11AJLITod'ay
                                   > 400 0 F            0.70 sec (S        4.6)    Position 26 temperature corrected Control Rod Scram              Independent Verification performed by:            11AJLITod'ay
: 1. V.
: 1. V.
Line 775: Line 752:
----------------~---------,-----~--------~----------------
----------------~---------,-----~--------~----------------
(Step 4.1)  Unit:    3 Associated control rod:              18-55        VfRO /today Record the CRD Temperature:                      VfRO /today Positio~  06 Scram Time              lculation (Step 4.2) Position 06 Scram Time:            2.599 sec        VfRO /today (St  4.3) Position 06 Penalty (from Table 4  low) :                        0.70  sec      VfRO /today (Step 4.4) Determine the Temperature Corrected Position 06 Control Rod Scram Time by adding the Position 06 Scram Time and Position 06 Penalty:                  3.299 sec        VfRO /today (Step 4.5) Maximum Notch Position 06 Scram Time allowed by Tech Spec Tab    3.1.4-1:                      3.35 sec        VfRO /Today Table 4: GE SIL 173 Position 06 Penalty CRD Temp          Position 06 Penalty
(Step 4.1)  Unit:    3 Associated control rod:              18-55        VfRO /today Record the CRD Temperature:                      VfRO /today Positio~  06 Scram Time              lculation (Step 4.2) Position 06 Scram Time:            2.599 sec        VfRO /today (St  4.3) Position 06 Penalty (from Table 4  low) :                        0.70  sec      VfRO /today (Step 4.4) Determine the Temperature Corrected Position 06 Control Rod Scram Time by adding the Position 06 Scram Time and Position 06 Penalty:                  3.299 sec        VfRO /today (Step 4.5) Maximum Notch Position 06 Scram Time allowed by Tech Spec Tab    3.1.4-1:                      3.35 sec        VfRO /Today Table 4: GE SIL 173 Position 06 Penalty CRD Temp          Position 06 Penalty
                   > 350 0 F and < 400 0 F
                   > 350 0 F and < 400 0 F 0.15 sec
                  -
0.15 sec
                           > 400 0 F            0.70 sec (Step 4.6) Position 06 temperature corrected Control Rod Scram Time Independent Verification performed by:            Io/ClLlI'oaay
                           > 400 0 F            0.70 sec (Step 4.6) Position 06 temperature corrected Control Rod Scram Time Independent Verification performed by:            Io/ClLlI'oaay
: 1. V.
: 1. V.
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EFFECTIVE DATE: _ _    _,,      1_
EFFECTIVE DATE: _ _    _,,      1_
1___      _..1_ _
1___      _..1_ _
_--
NAME:                                                    ISSUE DATE:
NAME:                                                    ISSUE DATE:
Last              First            M.1.
Last              First            M.1.
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RE-41 Rev. 9 Page 9 of 9 ATTACHMENT 1 3D Monicore Installed Thermal        s (Check one column for ea    Operational Condition)
RE-41 Rev. 9 Page 9 of 9 ATTACHMENT 1 3D Monicore Installed Thermal        s (Check one column for ea    Operational Condition)
Unit    2
Unit    2 Operational        tion    ALLOWED                NOT ALLOWED (Thermal        ing    (Thermal        ing Limits Implemented    Limits NOT      lemented AND operation          OR operation not a owed at this        a owed at this t        in time in the cycle)    the cycle)
    --------------------
Operational        tion    ALLOWED                NOT ALLOWED (Thermal        ing    (Thermal        ing Limits Implemented    Limits NOT      lemented AND operation          OR operation not a owed at this        a owed at this t        in time in the cycle)    the cycle)
Increased Core Flow
Increased Core Flow
(>100% to ~110% of rated) 55&deg; Feedwater rature Reduction 90&deg; Feedwater Temperature Reduction Prepared                                  IV:
(>100% to ~110% of rated) 55&deg; Feedwater rature Reduction 90&deg; Feedwater Temperature Reduction Prepared                                  IV:
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Signature / Title            Date Signature / Title            Date APPROVED FOR USE:
Signature / Title            Date Signature / Title            Date APPROVED FOR USE:
Signature / Title            Date EFFECTIVE DATE: _ _ _            < _ _ _  _<
Signature / Title            Date EFFECTIVE DATE: _ _ _            < _ _ _  _<
                                                                      < _ _
___
NAME:                                                    ISSUE DATE:
NAME:                                                    ISSUE DATE:
Last              First            M<I.
Last              First            M<I.
Line 991: Line 961:
Signature I Title            Date Signature I Title            Date Signature I Title            Date APPROVED FOR USE:
Signature I Title            Date Signature I Title            Date Signature I Title            Date APPROVED FOR USE:
Signature I Title            Date EFFECTIVE DATE: _ _ _        _-_ -_ _ _    _._
Signature I Title            Date EFFECTIVE DATE: _ _ _        _-_ -_ _ _    _._
                                                                        ._ _
___
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
Line 1,164: Line 1,132:
Signature {Title        Date Signature {Title        Date APPROVED FOR USE:
Signature {Title        Date Signature {Title        Date APPROVED FOR USE:
Signature { Title        Date EFFECTIVE DATE: _ _      _..      ,--_.,--
Signature { Title        Date EFFECTIVE DATE: _ _      _..      ,--_.,--
                                                                ,--_.,---
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
Line 1,222: Line 1,189:
                                                   *** NOTE ***
                                                   *** NOTE ***
IF this JPM is being performed in an area with other candidates such as Tabletop in a classroom, remind the candidates to NOT make any announcements out loud.
IF this JPM is being performed in an area with other candidates such as Tabletop in a classroom, remind the candidates to NOT make any announcements out loud.
:
                                                   *** NOTE ****
                                                   *** NOTE ****
Record the time using the clock above the Full Core Display. Time          =
Record the time using the clock above the Full Core Display. Time          =
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Signature I Title          Date EFFECTIVE DATE: _ _.----:'    _.1_ _ _----:'  __
Signature I Title          Date EFFECTIVE DATE: _ _.----:'    _.1_ _ _----:'  __
_.1_  _
_.1_  _
__
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.l.
Last                First            M.l.
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Signature I Title        Date Signature I Title        Date Signature I Title        Date APPROVED FOR USE:
Signature I Title        Date Signature I Title        Date Signature I Title        Date APPROVED FOR USE:
Signature I Title        Date EFFECTIVE DATE: _ _            ,-_---..:'--
Signature I Title        Date EFFECTIVE DATE: _ _            ,-_---..:'--
                                                          '---'---
NAME:                                                    ISSUE DATE:
NAME:                                                    ISSUE DATE:
Last              First            M.1.
Last              First            M.1.
Line 1,519: Line 1,483:
                                                 "'''''''''' NOTE: "''''''''''
                                                 "'''''''''' NOTE: "''''''''''
The Alternate Path portion of this JPM begins with the next step.              step .
The Alternate Path portion of this JPM begins with the next step.              step .
**
PLOR332CA Rev002                                                                                      Page 50f9
PLOR332CA Rev002                                                                                      Page 50f9


Line 1,559: Line 1,522:
(Cue: MO-2-13-041 green light is on, red light is off.)
(Cue: MO-2-13-041 green light is on, red light is off.)
   *27    Place control switch for MO-2-13-137,    P  Control switch for MO-2-13-137 is placed "Isol", to CLOSE.                            in the CLOSE position on Pane120C004C.
   *27    Place control switch for MO-2-13-137,    P  Control switch for MO-2-13-137 is placed "Isol", to CLOSE.                            in the CLOSE position on Pane120C004C.
:
(Cue: Acknowledge control switch i operation.)
(Cue: Acknowledge control switch i operation.)
28    Verify closed MO-2-13-137, "lsol".        P  MO-2-13-137 green light is verified ON at i
28    Verify closed MO-2-13-137, "lsol".        P  MO-2-13-137 green light is verified ON at i
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                                                                           ~~~~------------~I Licensed Operator Training                                          PLOR-083C Licensed Operator Requalification                                    009 M. J. Kelly                                                          Mda Reopen The Main Steam Isolation Vallves After a GP I Isolation APPROVALS:
                                                                           ~~~~------------~I Licensed Operator Training                                          PLOR-083C Licensed Operator Requalification                                    009 M. J. Kelly                                                          Mda Reopen The Main Steam Isolation Vallves After a GP I Isolation APPROVALS:
Signature I Title              Date Signature I Title              Date Signature I Title              Date Signature I Title              Date II APPROVED FOR USE:
Signature I Title              Date Signature I Title              Date Signature I Title              Date Signature I Title              Date II APPROVED FOR USE:
"
EFFECTIVE DATE: _ _              ,-----_.,-----
EFFECTIVE DATE: _ _              ,-----_.,-----
                                                              ,----,'----
NAME:                                                    ISSUE DATE:
NAME:                                                    ISSUE DATE:
Last              First            M.1.
Last              First            M.1.
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Signature I Title              Date Signature I Title              Date Signature I Title              Date APPROVED FOR USE:
Signature I Title              Date Signature I Title              Date Signature I Title              Date APPROVED FOR USE:
Signature I Title              Date EFFECTIVE DATE: _ _    _._.._. _ _ _      _._
Signature I Title              Date EFFECTIVE DATE: _ _    _._.._. _ _ _      _._
                                                                          ._ _
___
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
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Signature I Title      Date Signature I Title      Date APPROVED FOR USE:
Signature I Title      Date Signature I Title      Date APPROVED FOR USE:
Signature I Title      Date EFFECTIVE DATE: _ _      _..    ,--_.,--
Signature I Title      Date EFFECTIVE DATE: _ _      _..    ,--_.,--
                                                                ,--_.,---
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
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Signature I Title          Date APPROVED FOR USE:
Signature I Title          Date APPROVED FOR USE:
Signature I Title          Date EFFECTIVE DATE: _ _      _------'
Signature I Title          Date EFFECTIVE DATE: _ _      _------'
                                                        -----' _ _------'
_--.: _ __
__
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
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  !~ottom Dead Center" and both lights
  !~ottom Dead Center" and both lights
  .*          "OFF" when sync scope at ''Top Dead Center".)
  .*          "OFF" when sync scope at ''Top Dead Center".)
!:
PLOR322CA Rev001                                                                        Page 4 of 9
PLOR322CA Rev001                                                                        Page 4 of 9


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Signature I Title                Date Signature I Title              Date Signature I Title                Date Signature I Title                Date I APPROVED FOR USE:
Signature I Title                Date Signature I Title              Date Signature I Title                Date Signature I Title                Date I APPROVED FOR USE:
Signature f Title                Date EFFECTIVE DATE: _ _      _---.:'_
Signature f Title                Date EFFECTIVE DATE: _ _      _---.:'_
                                                          ---.:'_ _    _---:'_
                                                                        ---:'_ _
___
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
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Signature I Title          Date Signature I Title          Date Signature I Title          Date APPROVED FOR USE:
Signature I Title          Date Signature I Title          Date Signature I Title          Date APPROVED FOR USE:
Signature I Title          Date EFFECTIVE DATE: ______
Signature I Title          Date EFFECTIVE DATE: ______
_____-______ ____-_  -_ _
___
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.I.
Last                First            M.I.
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Signature I Title            Date Signature I Title            Date APPROVED FOR USE:
Signature I Title            Date Signature I Title            Date APPROVED FOR USE:
Signature I Title            Date EFFECTIVE DATE: _____
Signature I Title            Date EFFECTIVE DATE: _____
_____.____  .____._  . __
_ __
_
NAME:                                                    ISSUE DATE:
NAME:                                                    ISSUE DATE:
Last                First            M.1.
Last                First            M.1.
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EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET on
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET on
                 ~ ....IPM IPM                      QUALIFICATION MANUAL
                 ~ ....IPM IPM                      QUALIFICATION MANUAL D
              --------------------------------------
I I        OJT MODULE Licensed Operator Training                                              PLOR-075P Licensed Operator Requalification                              .. 015 J. R. Felice                                                    . . .* jav jav SCRAM SOLENOID DE-ENERGIZATION - UNIT 2 (T-213-2)
D I I        OJT MODULE Licensed Operator Training                                              PLOR-075P Licensed Operator Requalification                              .. 015 J. R. Felice                                                    . . .* jav jav SCRAM SOLENOID DE-ENERGIZATION - UNIT 2 (T-213-2)
APPROVALS:
APPROVALS:
Signature f Title                Date Signature f Title                Date Signature f Title                Date APPROVED FOR USE:
Signature f Title                Date Signature f Title                Date Signature f Title                Date APPROVED FOR USE:
Signature f Title                Date EFFECTIVE DATE: _ _      _.---.:
Signature f Title                Date EFFECTIVE DATE: _ _      _.---.:
                                                        .---.: _ _ _ _ _
___
NAME:                                                      ISSUE DATE:
NAME:                                                      ISSUE DATE:
Last                First            M.I.
Last                First            M.I.
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EXELON NUCLEAR Nuclear Generation Group O..IT/TPE O ..IT/TPE MATERIAL COVERSHEET l!:=dJ/[i)meriCk                II      Common JPM                    I ' ......'" ,"-"
EXELON NUCLEAR Nuclear Generation Group O..IT/TPE O ..IT/TPE MATERIAL COVERSHEET l!:=dJ/[i)meriCk                II      Common JPM                    I ' ......'" ,"-"
                                                              ,"-"**
                                                                   ** ",ATION MANUAL      D              O"IT MODULE PLOR-271P LICENSED OPERATOR REQUALIFICATION                                                      000 J. A. Verbillis                                                    TYIP~I~~* * *. *rl;1 rl;1 jav BACKUP INSTRUMENT NITROGEN TO ADS SYSTEM STARTUP AND OPERATION (Unit 3)
                                                                   ** ",ATION MANUAL      D              O"IT MODULE PLOR-271P LICENSED OPERATOR REQUALIFICATION                                                      000 J. A. Verbillis                                                    TYIP~I~~* * *. *rl;1 rl;1 jav BACKUP INSTRUMENT NITROGEN TO ADS SYSTEM STARTUP AND OPERATION (Unit 3)
APPROVALS:
APPROVALS:
Signature I Title                        Date Signature I Title                        Date APPROVED FOR USE:
Signature I Title                        Date Signature I Title                        Date APPROVED FOR USE:
I Title EFFECTIVE DATE: _ _              _,,
I Title EFFECTIVE DATE: _ _              _,,
                                                                        ,-------',--
                                                                        ,-------',---
NAME:                                                              ISSUE DATE:
NAME:                                                              ISSUE DATE:
Last                First                  M.1.
Last                First                  M.1.
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Initial          IC-91, 5% power Conditions Turnover          See Attached "Shift Turnover" Sheet Event      Malfunction            Event                                          Event No.            No.              Type'"                                      Description 1                              N    PRO      Secure drywell purge CRS 2                              R    URO      Power ascension with control rods CRS 3                              C    LlRO      Drifting contr*ol rod (Tech Spec)
Initial          IC-91, 5% power Conditions Turnover          See Attached "Shift Turnover" Sheet Event      Malfunction            Event                                          Event No.            No.              Type'"                                      Description 1                              N    PRO      Secure drywell purge CRS 2                              R    URO      Power ascension with control rods CRS 3                              C    LlRO      Drifting contr*ol rod (Tech Spec)
TS    PRO CRS 4                              C    PRO      Drywell chiller trip I place standby chiller in service CRS 5                            TS    CRS      ARI power supply failure (Tech Spec) 6                              I    URO      APRM trip with auto scram failure I manual reactor scram CRS 7                            M      ALL      Torus leak into secondary containment I emergency blowdown 8                              I    URO      Startup level control valve (LCV-8091) failure CRS 9                              C    PRO      Turbine bypclss jack fails (prevents rapid depressurization to the main CRS      condenser)
TS    PRO CRS 4                              C    PRO      Drywell chiller trip I place standby chiller in service CRS 5                            TS    CRS      ARI power supply failure (Tech Spec) 6                              I    URO      APRM trip with auto scram failure I manual reactor scram CRS 7                            M      ALL      Torus leak into secondary containment I emergency blowdown 8                              I    URO      Startup level control valve (LCV-8091) failure CRS 9                              C    PRO      Turbine bypclss jack fails (prevents rapid depressurization to the main CRS      condenser)
                      ..
.. (N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec
.. (N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec


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The main turbine will trip several minutes into this event as a result of the loss of Stator Cooling, complicating the crew's efforts to respond to the ATWS and challenging Primary Containment due to SRVactuation. When SBLC is initiated, RWCU will fail to automatically isolate, requiring the crew to manually isolate RWCU. In addition, the crew will not be able to restore normal instrument nitrogen, which will require aligning a backup source of nitrogen to the SRVs to ensure they are available for reactor pressure control. After RPV level has been lowered to control power, the ATWS will be terminated using T-214 "Venting the Scram Air Header".
The main turbine will trip several minutes into this event as a result of the loss of Stator Cooling, complicating the crew's efforts to respond to the ATWS and challenging Primary Containment due to SRVactuation. When SBLC is initiated, RWCU will fail to automatically isolate, requiring the crew to manually isolate RWCU. In addition, the crew will not be able to restore normal instrument nitrogen, which will require aligning a backup source of nitrogen to the SRVs to ensure they are available for reactor pressure control. After RPV level has been lowered to control power, the ATWS will be terminated using T-214 "Venting the Scram Air Header".
Initial          IC-92, 100% power Conditions Turnover        See Attached "Shift Turnover" Sheet Event      Malfunction              Event                                        Event No.            No.                Type*                                      Description 1                              N    PRO    Verify operability of Startup Source load tap changer CRS I    2                              C    URO    CRD pump trip / place standby CRD pump in service CRS 3                              TS    CRS    SBO line failure (TRM) 4                              C    PRO    SRV inadvertently opens (Tech Spec) / maximize torus cooling TS    CRS 5                              R    URO    Fast power reduction / pressure reduction due to SRV failure CRS 6                              M      ALL    Loss of stator cooling water / scram (electric ATWS) 7                              I    LlRO    RWCU fails to isolate on SBLC initiation I manually isolate RWCU CRS 8                              C    PRO    Unable to restore drywell instrument nitrogen I place alternate CRS    instrument nitrogen system(s) in service
Initial          IC-92, 100% power Conditions Turnover        See Attached "Shift Turnover" Sheet Event      Malfunction              Event                                        Event No.            No.                Type*                                      Description 1                              N    PRO    Verify operability of Startup Source load tap changer CRS I    2                              C    URO    CRD pump trip / place standby CRD pump in service CRS 3                              TS    CRS    SBO line failure (TRM) 4                              C    PRO    SRV inadvertently opens (Tech Spec) / maximize torus cooling TS    CRS 5                              R    URO    Fast power reduction / pressure reduction due to SRV failure CRS 6                              M      ALL    Loss of stator cooling water / scram (electric ATWS) 7                              I    LlRO    RWCU fails to isolate on SBLC initiation I manually isolate RWCU CRS 8                              C    PRO    Unable to restore drywell instrument nitrogen I place alternate CRS    instrument nitrogen system(s) in service
                      ..
   * (N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec
   * (N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec


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Initial        IC-93, 88% power Conditions Turnover        See Attached "Shift Turnover" Sheet Event      Malfunction              Event                                              Event No.            No.                Type*                                          Description 1                              N      PRO    Main Turbine stop valve functional test 1 RPS failure (Tech Spec)
Initial        IC-93, 88% power Conditions Turnover        See Attached "Shift Turnover" Sheet Event      Malfunction              Event                                              Event No.            No.                Type*                                          Description 1                              N      PRO    Main Turbine stop valve functional test 1 RPS failure (Tech Spec)
TS      CRS 2                              C      URO    Service Water pump trip 1 manual start of the standby pump CRS 3                              I      PRO    Orywell pressure instrument fails upscale without the expected half TS      CRS    scram (Tech Spec) 1 insert half scram lAW GP-25 4                              R      URO    Condensate pump trip with recirc runback failure 1 power reduction CRS 5                              M      ALL    Loss of #2 auxiliary bus 1 loss of condensate & feedwater I reactor coolant leak inside the drywell 6                              C      URO    RPS failure requires ARI to scram the reactor CRS 7                              I      URO    HPCI trip I RelC flow controller fails in automatic (transfer to manual CRS    control) 8                              I      PRO    Containment spray logic failure hampers effort to spray the CRS    containment, requiring crew to use alternate RHR loop
TS      CRS 2                              C      URO    Service Water pump trip 1 manual start of the standby pump CRS 3                              I      PRO    Orywell pressure instrument fails upscale without the expected half TS      CRS    scram (Tech Spec) 1 insert half scram lAW GP-25 4                              R      URO    Condensate pump trip with recirc runback failure 1 power reduction CRS 5                              M      ALL    Loss of #2 auxiliary bus 1 loss of condensate & feedwater I reactor coolant leak inside the drywell 6                              C      URO    RPS failure requires ARI to scram the reactor CRS 7                              I      URO    HPCI trip I RelC flow controller fails in automatic (transfer to manual CRS    control) 8                              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
* (N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)ajor, (TS) Tech Spec


Revision as of 05:06, 12 March 2020

Final Operating Exam (Sections a, B, and C) (Folder 3)
ML093620021
Person / Time
Site: Peach Bottom  
Issue date: 12/07/2009
From:
NRC Region 1
To:
Shared Package
ML091380320 List:
References
TAC U01792
Download: ML093620021 (254)
v • d • e


Text

{{#Wiki_filter:EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET Common II JPM D QUALIFICATION MANUAL. MANUAL_ I OJT MODULE Licensed Operator Training PLOR-266C Licensed Operator Requalification 000 J. A. Verbillis jav Evaluation of High CRD Temperature on Control Rod Scram Time APPROVALS: Signature / Title Date S ig nature / Title Sig Date Signature / 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 PLOR266C RevOOO Page 1 of 5

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator TASK-..IPM TASK-..IPM DESIGNATOR: 20110504011 PLOR-266C KIA: G2.1.32 RO: 3.8 TASK DESCRIPTION: Evaluation of High CRD Temperature on Control Rod Scram Time 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 IPMs 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 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 ....IPM, IPM, though listed in the task standard, is not to be given to the examinee.

PLOR266C RevOOO Page 2 of 5

B. TOOLS AND EQUIPMENT

1. AO 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time"
2. Tech Spec Table 3.1.4-1 "Control Rod Scram Times" (Att 3)
3. Calculator
4. ANSWER KEY for EVALUATOR (Att 2)

C. REFERENCES

1. AO 3.8, Rev. 0 "Evaluation of High CRD Temperature on Control Rod Scram Time"
2. Tech Spec 3.1.4 and Bases D. TASK STANDARD
1. Satisfactory task completion is indicated when steps 4.1 through 4.5 of the AO are complete.
2. Estimated time to complete: 20 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, complete steps 4.1 through 4.5 of AO 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time". I will describe initial plant conditions and provide you the materials required to complete this task. I will provide a copy of the required Tech Spec table.

F. TASK CONDITIONS/PREREQUISITES

1. Unit 3 is at 100% power.
2. Control Rod 18-55 temperature is 375 OF and cannot be lowered.
3. System Manager has provided the latest Scram Time data for CR 18-55:

Position 06 - 2.599 Sec Position 26 - 1.396 Sec Position 36 - 0.844 Sec Position 46 - 0.343 Sec G. INITIATING CUE The Control Room Supervisor directs you to complete steps 4.1 through 4.5 of AO 3.8 "Evaluation of High CRD Temperature on Control Rod Scram Time" for Unit 3 Control Rod 18-55, and identify any out-of-specification conditions. PLOR266C RevOOO Page 3 of 5

H. PERFORMANCE CHECKLIST II STEP STEP ACT STANDARD NO 

                                                 *** NOTE ***

Attachment 3 is a copy of AO 3.8 formatted as an answer key. Copy of AO 3.8 provided to Candidate should NOT CONTAIN ANY DATA. 1 Obtain a BLANK copy of AO 3.8. P AO 3.8, "Evaluation of High CRD (CUE: Provide candidate with a BLANK Temperature on Control Rod Scram copy of AO 3.8 - ENSURE YOU DO NOT Time" is obtained. HAND OUT ANSWER KEY -Also provide candidate with Tech Spec Table 3.4.1-1) 

     *2    Record Unit, Control Rod number, and           P   Unit 3, Control Rod 18-55, and 375°F CRD Temperature on AO 3.8, Pages 5, 6,             recorded on AO 3.8, Pages 5, 6, 7, and 8 7, and 8
                                                 *** NOTE ***

Data obtained for AO 3.8 Step 4.2 is given in Initiating Cue. 

     *3    Record the Position 46 (36, 26, 06) scram      P   Scram Time recorded - Position 46 (36, time in appropriate location in AO 3.8             26, 06) Scram Time (0.343, 0.844, 1.396, 2.599 sec, respectively) and record in appropriate location in AO 3.8.
     *3    Determine the Position 46 (36, 26, 06)         P   Correctly determine the Position 46 (36, Penalty and record in AO 3.8                       26,06) Penalty (0.07,0.14,0.17,0.15 sec, respectively) and record in appropriate location in AO 3.8.
     *4    Add the Position 46 (36, 26, 06) Scram         P   Scram Time and Penalty summed Time to the associated Penalty and                 correctly - Position 46 (36, 26, 06) - (.413 record in AO 3.8                                  0.07,0.14,0.17,0.15 sec, respectively) and record in AO 3.8.
     *5     Record the Maximum Notch Scram Time           P   Correctly determine the Maximum Notch allowed by Tech Spec Table 3.1.4-1 for            Scram Time allowed by Tech Spec Table Position 46 (36, 26, 06) and record in AO         3.1.4 Refer to Key provided as 3.8                                                PLOR266C RevOOO At 3
     *6     Review data for out of specification          P    Identify that all values are in specification conditions
     *7     Inform Control Room Supervisor of             P   Control room Supervisor is notified of task completion of AO 3.8 to the point of              completion.

requiring Independent Verification. (Cue: acknowledge communication.) II PLOR266C RevOOO

STEP STEP TAcT STANDARD NO 8 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 steps 4.1 through 4.5 of the AO are complete, completion of Attachment 1, declaration of no out of specification conditions, and identification of the requirement to have an Independent Verification performed prior to taking further action, the Control Room Supervisor should be informed, the evaluator will terminate the exercise. PLOR266C RevOOO Page 5 of 5

TASK CONDITIONS/PREREQUISITES

1. Unit 3 is at 100% power.
2. Control Rod 18-55 temperature is 375 of and cannot be lowered.
3. System Manager has provided the latest Scram Time data for CR 18-55:

Position 06 - 2.599 Sec Position 26 - 1.396 Sec Position 36 - 0.844 Sec Position 46 - 0.343 Sec INITIATING CUE The Control Room Supervisor directs you to complete steps 4.1 through 4.5 of AO 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time" for Unit 3 Control Rod 18-55, and identify any out-of-specification conditions.

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 Page 1 of 10 NHN:nhn Exelon Nuclear Pe Bottom Units 2 and 3 AO 3.8 EVALUATION OF HIGH CRD TEMPERATURE ON CONTROL 1.0 PURPOSE is procedure provides the instructions necess the impact of high CRD hydraulic temperature on con time, as recommended by GE SILs 173 and 173S1, to compliance with Technical Specifications 3.1.3 2.0 ISITES 2.1 CRD hydraulic 3.0 PRECAUTIONS 3.1 High CRD hydra ic temperatu the associated control rod being declared decla accordance with Technical Specification 3.1.4. TeeTec Speci cations 3.1.3 AND 3.1.4 shou be reviewe his procedure is entered. 4.0 PERFORMANCE STEPS ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 Page 2 of 10 NOTES

1. The control rod scram times for Positions 46, 36, 26, and 06 for the associated control rod will be obtained from s located in the System Status Files of the last performance of eithe ST'-R-003-475-2(3) , ST-R-003 485-2(3) or ST-R-003-495-2(3) ,

from the control rod scram time database located on ccomp drive S:\Scram Time\scramtime.mdb.

2. The last performance of ST-R-003 475-2(3), ST-R-003 ST-R-003- or ST-R-003-495-2(3) is reviewed first to determine asso ated control rod was included in the scope If so, the necessary scram times will obtained source s the control rod scram time en updated to reflect latest scram time
3. IF the associated control rod was NOT n t scope of testing for the last performance of ST 2(3),

ST-R-003-485-2(3) , or ST-R-003-495-2 t necessary scram times will be obtained from t rod scram time database.

4. Attachment 1, "Control Rod Scr Impact Calculation", will be to document perfo performa 's procedure.

4.1 IF CRD hydraulic lowered low 350 0 F, THEN REC , control rod number AND CRD erature on Attachment 1 pages 7, 8, 9, and 10. ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 Page 3 of 10 4.2 OBTAIN control rod scram t s Positions 46, 36, 26, AND 06 associated control as follows: 1.0 IF control rod was scram t in the last per of ST-R-003 475 2(3), ST-R-003-485 ST-R-003-495-2(3) during the current operating c THEN RECORD the control rod scram times docume the Surveillance Test in the appropriate Att 1 pages 7, 8, 9, 10. 2.0 IF control rod was NOT t of Surveillance Tests in p, THEN OBTAIN latest control rod uring the current operating cycle from rod scram t database located on computer cram Time\scramtime.mdb AND RECORD appropriate location Attachment 1 , 9, and 10. 3.0 IF control rod scram the current ope rat cyc could not be obta' one of the previous steps, THEN CONTACT E AND OBTAIN the latest control rod scram ti current ope rat cycle AND RECORD ate location in Att 1 pag 10. 4.3 DETERMINE the 46{36, 26, 06) Penalty using Table 1(2, 3, ge 7(8, 9, 10) AND RECORD in the appropriate Attachment 1. 4.4 ADD the Posi 46(36, 26, 06) control rod scram time to ion 46(36, 26, 06) penalty to determine the e .~orrected Position 46(36, 26, 06) control rod AND RECORD in the ate location in 1. Maximum Notch 46(36, 26, 06} Scram Time all Table 3.1.4-1 in appropriate location 1. DIRECT an Independent Ve f ion be performed all entries on Attachment 1 AND DOCUMENT in the appropriate location Attachment 1. ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 Page 4 of 10 4.7 DIRECT Reactor Engineering to perform ST-R-003 480-2(3), 

         "Average Scram T         For ODYN/B Minimum Critical Power Ratio (MCPR) requirements," within 72 hours.

Person Contacted: T Date: 4.8 DETERMINE if the ure corrected Position

06) cont rod scram is greater than th 46(36, 26, 06) Scram Time allowed by Tech Spec Table 3.1.4-1.

1.0 IF ALL temperature correct contr contr-c' cram times are less than OR equal to the Maximu Scram Time allowed by Tech Table 3.1. GO to Step 4.11. OTHERWISE, N/A. 2.0 IF ANY temperature correct rol rod scram time is er than the Maxi Scram Time allowed by Tech Spec Table 3.1.4 GO to Step 4.9. OTHERWISE N/A. 4.9 IF ANY temperature c rod scram time is greater than the M Time allowed by Tech Spec 3.1.4 control rod "slow" AND COMPLY with Tec fications 3.1.3 AND 3.1.4. OTHERWISE, N/ 4.10 IF ANY contr od scram time is greater than 7 seconds to p sition 06, THEN DECLARE control rod inoperable wj~h Technical Specificat 3.1.3. OTHERWISE, CAUTIONS CAU'rIONS

1. In accordance with Technical Specification 3.1.4, specific combinations "slow" control rods require a plant shutdown.

The intent of the following step is to ensure any temperature corre on for a control rod that has the POTENTIAL to require a plant shutdown is verified since a plant shutdown either will be, or will not be, performed based on the calculation.

2. The following step is not ended to rest performance of a plant shutdown required by Technical Specification 3.1.4.

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 Page 5 of 10 4.11 REGARDLESS of whether or not the rod was evaluated as slow, IF the control rod is adjacent to another "slow" control rod OR IF 12 other control rods have already been declared "slow", THEN IMMEDIATELY NOTIFY the EDM AND DIRECT tha Engineering IMMEDIATELY verify the accuracy of the temperature corrected control rod scram time calcul OTHERWISE, N/A. 4.12 DOCUMENT Shift Management review 4.13 INITIATE an Issue to correct the condition. 4.14 NOTIFY the CRD System Manager that performed AND FORWARD Attachment 1 to the Sy ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 Page 6 of 10 5.0 CONTROL STATIONS 5.1 None

6.0 REFERENCES

6.1 GE SIL 173 6.2 GE SIL 173S1, Revision 1 7.0 TECHNICAL SPECIFICATIONS 7.1 3.1.3 7.2 3.1.4 8.0 INTERFACING PROCEDURES 8.1 ARC 2(3)11 G-5, "CRD 8.2 ST-R-003-475 2(3), "CRD Timing Follow Reactor Scram" 8.3 ST-R-003-485-2(3), " Timing of Selected Control Rods" 8.4 ST R-003-495 Insertion Timing of Selected Control Rods ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 7 10 : Control Rod Scram Time Calculat Date (Step 4.1) Un 3 Asso control rod: 18-55 CRD Temperature: (Step 4.2) Pos ion 46 Scram Time: 0.343 (Step 4. 3) Posit 46 Penalty (from e low): ___1__ ___ 1__- (Step 4.4) Det ne the Temperature Correct Position 46 Control Rod Scram Time by ng t Position 46 Scram Time and Position 46 Penalty: sec ___1__ ___ 1__- (Step 4.5) Maximum Notch Scram Time allowed by Tech Spec e 3.1.4 1: 0.44 sec Table 1: Position 46 Penalty Position 46 Penalty 

                                 < 400 0 F      0.07 sec
                         > 400 0 F              0.35 sec temperature corre Independent Verification pe                   ___1_

___ 1_ _ _-

1. V.

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 Page 8 of 10 : Control Rod Scram Time Impact Calculation Initial/Date (Step 4.1) \Jnit: 3 Associated control rod: 18-55 Record the CRD Temperature: Position 36 Scram Time Penalty Calculation (Step 4.2) Position 36 Scram Time: 0.844 --_/_-- (Step 4.3) Position 36 Penalty (from Table 2 below): --_/_-- (Step 4.4) Determine the Temperature Corrected Position 36 Control Rod Scram Time by adding the position 36 Scram Time and Position 36 Penalty: sec --_/_-- (Step 4.5) Maximum Notch Position Scram Time allowed by Tech Spec Table 3.1.4-1: 1.08 sec --_/_-- Table 2: Position 36 Penalty Position 36 Penalty F 0.14 sec 

                         > 400 0 F           0.60 sec temperature corrected Control Independent Verification performed by:       --_/_--
1. V.

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 Pa 9 of 10 : Control Rod Scram Time T Calculation Initial Date

~----------------

(Step 4.1) Unit: 3 Associated control rod: 18-55 Record the CRD Temperature: Position 26 Scram Time Penalt Calculation (Step 4.2) Position 26 Scram Time: 1.396 -- - 

                                                                   /---

(Step 4.3) Position 26 Penalty (from Table 3 below): (S 4.4) Determine the Temperature Corrected Position 26 Control Rod Scram Time by adding t Position 26 Scram Time and Position 26 Penalty: sec 4.5) Maximum Notch Scram Time allowed by Tech Table 3.1.4-1: 1.83 sec Table 3: Position 26 Penalty Pos ion 26 Penalty F 0.17 sec 0.70 sec temperature corrected Control Independent Veri cation performed by:

1. V.

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE

ANSWER KEY - DO NOT HAND OUT TO CANDIDATE AO 3.8 Rev. 0 10 of 10 Attachrrent 1: Cont Rod Scram Time ct Calculation 4.1 ) Un 3 Associated control rod: 18-55 Record the CRD Temperature: Position 06 Scram T 4.2) Position 06 Scram Time: 2.599 1_ 1__ _- 4.3) Posit 06 Penalty Table 4 below): (St 4.4) Dete the Temperature Corrected Position 06 Control Rod Scram T by adding t Position 06 Scram Time and Position 06 Penalty: sec ___1_ ___ 1_ _ _- (St 4.5) Maximum Notch Position Scram Time allowed by Spec Table 3.1.4-1: 3.35 sec ___1__ ___ 1__- Table 4: Position 06 Penalty Position 06 Penalty 

                                  < 400 0 F      0.15 sec
                          > 400 0 F              0.70 sec

( temperature corrected Cont Rod Independent Veri cation performed by: I. V. Shift Management of Attachment 1 9, and 10 performed by: ANSWER KEY - DO NOT H.A.ND OUT TO CANDIDATE

Control Rod Scram Times 3.1.4 Tab 1e 3. 1 .4-1 (page 1 of 1) Tab1 Control Rod Scram Times - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOTES - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

1. OPERABLE control rods with scram times not within the limits of this Table are considered "slow."
2. Enter applicable Conditions and Required Actions of LCO 3.1.3, "Control Rod OPERABILITY," for control rods with scram times> 7 seconds to notch position 06. These control rods are inoperable, in accordance with SR 3.1.3.4, and are not considered "slow."

SCRAM TIMES WHEN REACTOR STEAM DOME PRESSURE 

                                                                                             ~ 800 pSig(a)(b)

NOTCH POSITION (seconds) 46 0.44 36 1.08 26 1.83 06 3.35 (a) Maximum scram time from fully withdrawn position, based on de-energization of scram pilot valve solenoids at time zero. (b)When reactor steam dome pressure is < 800 psig, established scram time limits apply. PBAPS UNIT 3 3.1-14 Amendment No. 214

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET h Bottom 

              ~      JPM               D      QUALIFICATION MANUAL           OJT MODULE Licensed Operator Training                                     PLOR-251C Licensed Operator Requalification                              001 M. J. Kelly                                                    jav Compliance with Asymmetric Feedwater Heating Operation (AFTO)

APPROVALS: Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE: I Title 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 PLOR251C Rev001 Page 1 of6

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator TASK-JPM DESIGNATOR: 25903604021 PLOR-251C KIA: G2.1.7 RO: 4.4 TASK DESCRIPTION: Asymmetric Feedwater Temperature Operation (AFTO} 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 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) ..IPMs, completion within the estimated time (listed in For time critical ..IPMs, 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.

PLOR251 C Rev001 Page 2 of6

B. TOOLS AND EQUIPMENT

1. AO 6.7-2 "Asymmetric Feedwater Temperature Operation (AFTO)"
2. RE-41 "lnstaliationNerification of the 3D Monicore Thermal Operating Limits"
3. PLOR251 CAt 2 - Prepared RE-41 Attachment 1
4. Calculator C. REFERENCES
1. AO 6.7-2, Rev. 6 "Asymmetric Feedwater Temperature Operation (AFTO)"
2. RE-41 , Rev 9 "lnstaliationNerification of the 3D Monicore Thermal Operating Limits" D. TASK STANDARD
1. Satisfactory task completion is indicated when steps 1.1 through 2.2 of Attachment 2 of AO 6.7-2, Asymmetric Feedwater Temperature Operation (AFTO), are properly completed.
2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to assure compliance with regulations during asymmetric feed water temperature operation 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 experienced a loss of feedwater heating.
2. OT-104 "Positive Reactivity Insertion" was entered and reactor power was lowered to 89% power and is presently stable.
3. It was determined that feedwater heating is asymmetric and procedure AO 6.7-2 "Asymmetric Feedwater Temperature Operation (AFTO)" was entered.
4. PMS Computer point NSS018 is INVALID.
5. All reactor feedwater pumps are in sen/ice.
6. Feedwater temperatures as read on TR-2151 are as follows:

A feedwater temperature = 335 degrees F B feedwater temperature =335 degrees F C feedwater temperature =300 degrees F PLOR251C Rev001 Page 3 of6

G. INITIATING CUE The Control Room Supervisor directs you to perform Attachment 2, "Feedwater Temperature Reduction Monitoring Requirements" of AO 6.7-2, "Asymmetric Feedwater Temperature Operation" PLOR251C Rev001 Page 4 af6

H. PERFORMANCE CHECKLIST Ii STEP STEP ACT STANDARD NO 1 Obtain a copy of AO 6.7-2. P AO 6.7-2 "Asymmetric Feedwater Temperature Operation (AFTO)", is (Cue: Provide a copy of AO 6.7-2 and obtained. RE-41 Attachment 1 to the Examinee) AO 6.7-2, Attachment 2, "Feedwater Temperature Reduction Monitoring Requirements", is referenced. 2 Determine that second bullet of step 1.1 P Determine that average feedwater of Attachment 2 of AO 6.7-2 is applicable temperature has to be calculated using since PMS Computer point NSS018 is Attachment 2 Exhibit 1 of AO 6.7-2. INVALID. Sign-off Attachment 2 Exhibit 1. (Cue: If necessary, repeat Task/Prerequisite Condition that PMS Mark the first part of step 1.1 of Computer point NSS018 is INVALID.) Attachment 2 of AO 6.7-2 as "N/A". 

     *3  Calculate average feedwater temperature      P  Since PMS Computer point NSS018 is value using Attachment 2 Exhibit 1              INVALID, per step 1.1 of AO 6.7-2 the "Determining Feedwater Injection                Examinee will use Attachment 2 Exhibit 1 Temperature Using TR-2151".                     "Determining Feedwater Injection Temperature Using TR-2151" to calculate (Cue: If necessary, repeat                      the average feedwater temperature value.

Task/Prerequisite Conditions that: Examinee inserts values of 335, 335 and A FW temperature =335 degrees F 300 degrees F respectively into Exhibit 1. B FW temperature =335 degrees F C FW temperature =300 degrees F, The average feedwater injection temperature with 3 in-service reactor And that all reactor feedwater pumps are feedwater pumps is determined to be in service.) 323.3 degrees F. 4 Determine that 55 OF feedwater P Candidate references RE-41, Att 1 to temperature reduction is applicable by determine that 55 OF feedwater reviewing RE-41, Att 1 temperature reduction IS allowed. 5 Identify that Section 2.0 (of Att 2) IS P Candidate identifies Section 2.0 of Att 2 is applicable applicable (See step 1.2) 6 Identify that Section 3.0 (of Att 2) IS NOT P Candidate identifies Section 3.0 of Att 2 is applicable NOT applicable (See step 1.2) PLOR251C Rev001 Page 5 of6

STEP STEP STANDARD NO 

  *7  Determine that Unit 2 is operating in the      P  Compare the feedwater temperature 55 degree Feedwater Temperature                   determined above (323.3 degrees F)

Reduction Region of Attachment 2, against the Feedwater Temperature Figure 1 "Feedwater Temperature Limits". Reduction Region Curve located on Attachment 2, Figure 1 "Feedwater (Cue: If necessary, repeat Temperature Limits" of AO 6.7-2. Task/Prerequisite Condition that Unit 2 is at 89% reactor power and stable.) Examinee should plot 323.3 degrees F at 3127 MWth (0.89 times 3514 MWth) on Attachment 2, Figure 1 (55 of Curve). 8 Exit Attachment 2, "Feedwater P Step 2.2 of Attachment 2 is referenced. Temperature Reduction Monitoring Since actual feedwater temperature was Requirements" of AO 6.7-2. determined to be in the 55 degree F Feedwater Temperature Reduction Region of Attachment 2, Figure 1, then Attachment 2 is EXITED. 9 Inform Control Room Supervisor of P Control room Supervisor is notified of task completion of Attachment 2 "Feedwater completion. Temperature Reduction Monitoring Requirements" of AO 6.7-2. (Cue: acknowledge communication.) 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) AN D procedures. Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When steps 1.1 through2.2 of Attachment 2, "Feedwater Temperature Reduction Monitoring Requirements", of AO 6.7-2 are completed the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR251C Rev001 Page 6 of6

TASK CONDITIONS/PREREQUISITES

1. Unit 2 experienced a loss of feedwater heating.
2. OT -104 "Positive Reactivity Insertion" was entered and reactor power was lowered to 89% power and is presently stable.
3. It was determined that feedwater heating is asymmetric and procedure AO 6.7-2 "Asymmetric Feedwater Temperature Operation (AFTO)" was entered.
4. PMS Computer point NSS018 is INVALID.
5. All reactor feedwater pumps are in service.
6. Feedwater temperatures as read on TR-2151 are as follows:

A feedwater temperature = 335 degrees F B feedwater temperature =335 degrees F C feedwater temperature =300 degrees F INITIATING CUE The Control Room Supervisor directs you to perform , "Feedwater Temperature Reduction Requirements" of AO 6.7-2, "Asymmetric Feedwater Temperature Operation".

RE-41 Rev. 9 Page 9 of 9 ATTACHMENT 1 3D Monicore Installed Thermal L s (Che one column for each Operational Condition) 2 Operational Condition ALLOWED NOT ALLOWED (Thermal Operating (Thermal Operating Limits Implemented Limits NOT Implemented AND operation OR operation not a owed at this a owed at this time in time the cycle) the cycle) Increased Core Flow (>100% to ~110% of rated) 55° Feedwater Temperature Reduction 90° Feedwater Temperature Reduction Prepared IV: 

               ~ P,ng    /  'Toaay             Otlier ~ P,ng    / 'Toaay By /Oate                            By /Date

EXELON NUCLEAR Nuclear Generation Group OJTJTPE MATERIAL COVERSHEET Peach Bottom D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING PLOR-257C ICENSED OPERATOR REQUALIFICATION 001 jav LATING THE 2A TBCCW HEAT EXCHANGER DUE TO A LEAK 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. M.I. EMPLOYEE ID#: COMPLETION DATE: COMMENTS: Training Review for Completeness: LMSCODE: LMS ENTRY: Signature/Date PLOR257C Rev001 Page 1 of6

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2002300401/ PLOR-257C KIA: 2.2.41 URO: 3.5 SRO: 3.9 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. ..IPM Performance
a. "Control Room" ....IPMs IPMs 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" ....IPMs, IPMs, 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.

PLOR257C Rev001 Page 2 of6

B. TOOLS AND EQUIPMENT

1. Full Set of M-300 Series P & IDs C. REFERENCES
1. P&ID M-314 sheet 2, Rev. 61
2. P&ID M-316 sheet 2, Rev. 61
3. OP-AA-108-101 "Control of Equipment and System Status" D. TASK STANDARD
1. Satisfactory task completion is indicated when the isolation points and venUdrain paths for the TBCCW and service water side of the 2A TBCCW 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 2A TBCCW heat exchanger.

F. TASK CONDITIONS/PREREQUISITES A suspected tube leak has been identified on the standby 2A Turbine Building Closed Cooling Water (TBCCW) heat exchanger 2AE038. The Work Control Supervisor will be developing an Abnormal Component Position Sheet for isolation, venting, and draining of the 2A TB CCW 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 2A TBCCW heat exchanger. Document your results on the CUE SHEET. PLOR257C Rev001

H. PERFORMANCE CHECKLIST II STEP NO STEP ACT STANDARD 1 Locate the component that is leaking on P Locate 2AE038 on M-316 sheet 2, P&ID drawings M-316 sheet 2 (TBCCW (Coordinates H-5) and on M-314 sheet 2 side) and M-314 sheet 2 (Service Water (Coordinates H-4). side). (Cue: Provide the candidate(s) with full set of M-300 series P & IDs) (Cue: If asked, inform candidate(s) that PIMS is down for IT maintenance) 

                                                *** 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 TBCCW and Service Water sides of the heat exchanger. 

      *2   Close HV-2-34-24275A "2AE038 TBCCW            P   Identifies that HV-2-34-24275A "2AE038 Inlet Block Valve".                               TBCCW Inlet Block Valve" must be CLOSED in order to isolate TBCCW to (Cue: Acknowledge that isolation point            the heat exchanger.

has been selected.) 

      *3   Close HV-2-34-24278A "2AE038 TBCCW            P   Identifies that HV-2-34-24278A "2AE038 Outlet Block Valve".                              TBCCW Outlet Block Valve" must be CLOSED in order to isolate TBCCW to (Cue: Acknowledge that isolation point            the heat exchanger.

has been selected.) 

      *4   Uncap and open HV-2-34-24359A                 P   Identifies that HV-2-34-24359A "2AE038 "2AE038 Lower Vent Valve"                         Lower Vent Valve" must be UNCAPPED and OPEN in order to VENT the lower AND/OR                           section of the 2A TBCCW heat exchanger Uncap and open HV-2-34-24276A "2AE038 Upper Vent Valve"                                          AND/OR (Cue: Acknowledge that vent point(s)              HV-2-34-24276A "2AE038 Upper Vent has been selected.)                               Valve" must be UNCAPPED and OPEN in order to VENT the upper section of the 2A TBCCW heat exchanger.

PLOR257C Rev001 Page 4 of 6

STEP NO STEP ACT STANDARD 

 *5   Uncap and open HV-2-34-24277A             P  Identifies that HV-2-34-24277A "2AE038 "2AE038 Drain Valve"                         Drain Valve" must be UNCAPPED and OPEN in order to DRAIN the TBCCW (Cue: Acknowledge that drain path has        side of the 2A TBCCW heat exchanger.

been selected.) 

 *6   Close HV-2-30-21774A "2AE038 Service      P  Identifies that HV-2-30-21774A "2AE038 Water Inlet Block Valve".                    Service Water Inlet Block Valve" must be CLOSED in order to isolate Service (Cue: Acknowledge that isolation point       Water to the heat exchanger.

has been selected.) 

 *7   Close HV-2-30-21775A "2AE038 Service      P  Identifies that HV-2-30-21775A "2AE038 Water Outlet Block Valve".                   Service Water Outlet Block Valve" must be CLOSED in order to isolate Service (Cue: Acknowledge that isolation point       Water to the heat exchanger.

has been selected.) 

 *8   Uncap and open HV-2-30-21776A             P  Identifies that HV-2-30-21776A "2AE038 "2AE038 Service Water Inlet Drain Valve"     Service Water Inlet Drain Valve" must be UNCAPPED and OPEN in order to AND  lOR                     DRAIN the Service Water side of the 2A TBCCW heat exchanger Uncap and open HV-2-30-21777A "2AE038 Service Water Low Point Drain                         AND  lOR Valve" HV-2-30-21777A "2AE038 Service Water AND/OR                       Low Point Drain Valve" must be UNCAPPED and OPEN in order to Uncap and open HV-2-30-21778A                DRAIN the Service Water side of the 2A "2AE038 Service Water High Point Drain       TBCCW heat exchanger.

Valve" AND lOR (Cue: Acknowledge that drain point{s) has been selected.) HV-2-30-21778A "2AE038 Service Water High Point Drain Valve" must be UNCAPPED and OPEN in order to DRAIN the Service Water side of the 2A TBCCW heat exchanger. 

 *9   Uncap and open HV-2-30-21779A             P  Identifies that HV-2-30-21779A "2AE038 "2AE038 Service Water Vent Valve"            Service Water Vent Valve" must be UNCAPPED and OPEN in order to VENT (Cue: Acknowledge that vent point(s)         the Service Water side of the 2A TBCCW has been selected.)                          heat exchanger.

PLOR257C Rev001

STEP NO STEP ACT STANDARD 10 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.) 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 the TBCCW and Service Water side isolation points, vent paths, and drain paths to the 2A TBCCW heat exchanger have been identified, and the Control Room Supervisor informed, the evaluator will terminate the exercise. PLOR257C Rev001 Page 6 of6

TASK CONDITIONS/PREREQUISITES A suspected tube leak has been identified on the standby 2A Turbine Building Closed Cooling Water (TBCCW) heat exchanger 2AE038. The Work Control Supervisor will be developing an Abnormal Component Position Sheet for isolation, venting, and draining of the 2A T8 CCW 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 2A TBCCW heat exchanger. Document your results on this CUE SHEET

EXELON NUCLEAR Nuclear Generation Group OJTrrPE MA"rERIAL COVERSHEET Peach Botto Common 

              ~      JPM                      QUALIFICATION MANUAL           OJT MODULE LICENSED OPERATOR TRAINING                                       LOR-341CA LlCENSD OPERATOR REQUALIFICATION J. A. Verbillis PERFORM STATE I LOCAL EVENT NOTIFICATIONS FOR A DECLARED EMERGENCY (Alternate Path: Incomplete Form)

APPROVALS: Signature I Title Date Signature f 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: SignaturelDate PLOR341 CA RevOOO Page

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2950110501/ PLOR-341CA KIA: G2.4.39 LlRO: 3.9 SRO: 3.8 TASK DESCRIPTION: PERFORM STATE / LOCAL EVENT NOTIFICATIONS FOR A DECLARED EMERGENCY (Alternate Path: Incomplete Form) 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 pelformed in the Control Room all perform steps (P) shall be simulated (S).
b. When performing "In-Plant" JPlVls, 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.

PLOR341 CA RevOOO Page 2 of6

B. TOOLS AND EQUIPMENT

1. EP-MA-114-100, Mid-Atlantic State/Local Notifications, Rev. 13.
2. EP-MA-114-1 00-F-01, State/Local Event Notification Form, Rev. G C. REFERENCES
1. EP-MA-114-100, Mid-Atlantic State/Local Notifications, Rev. 13.

D. TASK STANDARD

1. Satisfactory completion of this task is indicated when the errors on the State/Local Event Notifications have been identified and Notifications have been initiated.
2. Estimated time to complete: 13 minutes - Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, make State/Local Notifications in accordance with EP-MA-114-EP-MA-114 100, Mid-Atlantic State/Local Notifications. I will describe the initial conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES 

     *** THIS IS A TIME CRITICAL JPM ***
1. A transient has occurred on Peach Bottom Unit 2.
2. The Shift Manager, acting as the Station Emergency Director, has completed the initial classification of the event and prepared the State/Local Notification Form, EP-MA-114-EP-MA-114 100-F-01.
3. The event is classified as an Alert.
4. Another operator has been assigned to fax the State/Local Notification Form to the TSC and the EOF.

G. INITIATING CUE As the communicator, complete the required State and Local 1S-minute Notifications in accordance with Step 4.2 of EP-MA-114-100, Mid-Atlantic State/Local Notifications using the provided STATE/LOCAL NOTIFICATION FORM. PLOR341 CA RevOOO Page 3 of6

H. PERFORMANCE CHECKLIST II STEP STEP STANDARD I ACT NO NOTE TO EVALUATOR: When the cue is provided to the candidate, then WRITE the "DECLARED AT TIME" (2 minutes previous to actual time) on the State/Local Event Notification form in Section 3c and give it to the candidate. Record the time using the clock above the Full Core Display. Start Time =___ 

                                                                                            = ___

1 Receive from the SED the in-progress P Candidate receives a copy of EP-MA-EP-MA copy of EP-MA-114-100, "Mid-Atlantic 114-100, Mid-Atlantic State/Local State/Local Notifications" AND EP-MA EP-MA- Notifications AND the filled out EP-MA-EP-MA 114-100-F-01, "State/Local Event 114-100-F-01, State/Local Event Notification Form." Notification Form. (Cue: Provide the examinee with a copy of EP-MA-114-100 AND Attachment 2 of this JPM). 2 Ensure that "Utility Message No." has P Candidate verifies that the "Utility been assigned using a sequential Message No." blank is filled in with the number. number "1". 3 Review form for completeness. P Candidate reviews form to ensure that appropriate blanks are filled in. 

                                                  **** NOTE: ****

The Alternate Path portion of this JPM begins with the next step. Notes to Evaluator: (1) There are THREE errors (omissions) intentionally included on the "completed" form handed to the candidate. It is expected that the candidate will identify all three errors in the first review, however it is possible the form may go back to the SED as many as three times to correct each error one at the time. Either way is acceptable. It will be the responsibility of the Evaluator to provide the missing data, using the key. (2) It is also possible that the candidate will nc~t recognize one or more of the errors. If the candidate is able to recognize and correct all errors without communicating any false data, then the standard is met. 

      *4       Recognize "Emergency Director                 P    Candidate recognizes that the Shift Approval" signature has NOT been                   Manager signature in the ED approval entered.                                           form is blank.

[I I PLOR341 CA RevOOO Page 4 of6

is~~ STEP NO 

    *5 I                     STEP STEP Recognize "Affected Unit" is not ACT P

STANDARD Candidate recognizes that the Affected specified. Unit is not specified. 

    *6    Recognize "4.b" is blank                       P   Candidate recognizes 4.b is blank.
    *7    Return form to Shift Emergency Director,       P   Candidate returns form to SED for identify above errors.                             correction of errors.

(Cue: Acknowledge errors and omissions, correct them lAW Att 3, and then return to candidate) (Cue: If asked, MET data has been verified correct.) 8 Confirm dial tone on NARS line. PIS Candidate picks up phone and listens for dial tone. (Cue: When candidate picks up receiver, tell them that they hear a dial tone.) 9 Dial the appropriate CODE (CAN No.) PIS Candidate dials CAN Number 833 into listed for the affected station. the phone. (Cue: acknowledge dialing of number). 10 Repeat the required message while P Candidate states: "This is the Exelon allowing agencies to come on line. Nuclear Peach Bottom Control Room. Please standby for a notification (Cue: acknowledge message.) message." 11 After 10-15 seconds, read the required P Candidate states: "This is the Exelon message. Nuclear Peach Bottom Control Room. Please standby to receive a notification message and respond as the roll is (Cue: acknowledge message.) called." 12 Conduct an initial roll call for the agencies P Call out each agency on the Peach listed on the State/Local Event Bottom 15 minute notification list on page Notification Form. 3 of the State/Local Event Notification Form. (Cue: respond with "here" or "present" or Write the time on the form as each another suitable term as each agency is agency responds. called.) NOTE TO EVALUATOR: Record the time using the clock above the Full Core Display. Stop Time = Completion of the Initial Roll Call is required to be completed within 15 minutes of the initial classification. AFTER the JPM is complete, compare the "Start Time" to the "Stop Time" to ensure that the elapsed time is less than or equal to 13 minutes. II PLOR341 CA RevOOO Page 5 of6

STEP STEP ACT STANDARD NO 13 Enter the time that the roll call was P Enter the time the roll call was completed completed. in the box on the bottom of the roll call box on page 2 of the form. This time is required to be less than 15 minutes from Declaration time. 14 Read the blocks from the approved P Read each of the notification form blocks notification form. one at a time using the Phonetic Alphabet and speaking slowly and clearly. 15 Repeat the roll call. P Call the roll for each agency and check the final roll call box as each agency (Cue: respond with "here" or "present" or responds. another suitable term as each agency is called.) 16 Ask if there are any questions. P Ask if there are any questions and wait for a response. (Cue: respond with "no questions".) 17 Read the required statement, 'This P Read the following: "This concludes the concludes the notification message". notification message". (Cue: acknowledge statement.) 18 Report to the Shift Manager/Emergency P Report that State/Local Notifications have Director that notifications have been been completed. completed. (Cue: acknowledge report.) 19 As an evaluator, ensure that you have P Positive Control Established. positive control of all exam material provided to examinees (Task Conditions/Prerequisites AND procedures). Under "ACT" P - must perform S - must simulate I. TERMINATING CUE: When the candidate reports that the State/Local Event Notifications are complete, the evaluator will be notified. The evaluator will then terminate the exercise. PLOR341 CA RevOOO Page 6 6

TASK CONDITIONS/PREREQUISITES 

       *** THIS IS A TIME CRITICAL JPM ***
1. A transient has occurred on Peach Bottom Unit 2.
2. The Shift Manager, acting as the Station Emergency Director, has completed the initial classification of the event and prepared the State/Local Notification Form, EP-MA-114-1 OO-F-01.
3. The event is classified as an Alert.
4. Another operator has been assigned to fax the State/Local Notification Form to the TSC and the EOF.

INITIATING CUE As the communicator, complete the required State and Local 1S-minute Notifications in accordance with Step 4.2 of EP-MA-114-100, Mid-Atlantic State/Local Notifications using the provided STATE/LOCAL NOTIFICATION FORM.

Exel EP-MA-114-100-F-01 Revision G Nuclear Page 1 of 3 STATE/LOCAL EVENT NOTIFICATION FORM UTILITY MESSAGE NO. 1 EMERGENCY DIRECTOR APPROVAL: PERFORM INITIAL ROLL CALL PRIOR TO TRANSMITTING - Refer to Page 3 of Form

1. CALL STATUS is: 2. This is

[X 1This is a DRIl.L. for [ 1LIMERICK / [X 1PEACH BOTTOM / [ lTMI [ 1This is an ACTUAL EVENT. My phone number is The current time is [Communicator will provide his/her NAME, PHONE NUMBER, and CURRENT TIME (in 24-hour clock) when notification is read] 3.a EMERGENCY CLASSIFICATION b. AFFECTED UNIT(S) is/are: d. THIS REPRESENTS NAN: [ ] UNUSUAL EVENT [ lONE [ llWO [ 1THREE [X llNITIAL DECLARATION [Xl ALERT [ ] ESCALATION [ 1SITE AREA EMERGENCY c. DECLARED AT: [ ] NO CHANGE [ lGENERALEMERGENCY TIME: 2 minutes ago (24-hrclock) [ 1REDUCTION [ lRECOVERY DATE: Toda'i's Date - IN CLASSIFICATION STATUS [ 1TERMINATION

4. a. EMERGENCY ACTION LEVEL (EAL) NO. is: MA3
b. A BRIEF NON-TECHNICAL DESCRIPTION OF THE EVENT is as follows:
5. NON-ROUTINE RADIOLOGICAL RELEASE STATUS is:

[X 1a. NO radiological release in-progress [ lb. AIRBORNE radiological release in-progress [ 1c. LIQUID radiological release in-progress [ 1d. Radiological release TERMINATED

6. METEOROLOGY is:
a. WIND DIRECTION is FROM: 15 (degrees)
b. WIND SPEED is: 12 (miles per hour)

Document Retention SRRS-ID - 5B.100

EP-MA-114-100-F-01 Revision G Page 2 of 3 STATE/LOCAL EVENT NOTIFICATION FORM

7. UTILITY PROTECTIVE ACTION RECOMMENDATION.: (a or b) - No action should be taken until government officials have been notified: by State:

[X 1a. NOT APPLICABLE (Unusual Event, Alert, Site Area Emergency, Termination or Recovery only) (Complete the following for Shelter or Evacuation for a General Emergency only for the applicable station): 1b The PROTECTIVE ACTION RECOMMENDATION (PAR) from the utility is: SHELTER 360 DEGREES FROM 0 MILES (SITE BOUNDARY) TO _ _ _ _MILES MILES SHE R THE FOLLOWING SECTORS FROM MILES TO [ 1 [ 1 E [ 1 S [ 1 NNE [ 1 ESE [ 1 SSW [ 1 NE [ 1 SE [ 1 SW [ 1 ENE 1 SSE [ 1 WSW AND The utility recommends that gove ent officials notify the eral public to take potassium iodide en (KI) for those sectors where shelter is advise remainder of the EPZ to monitor c.. 

  <C             EAS Messages.

m c.. en (!) 

  ..J EVACUATE 360 DEGREES FROM 0                                                   __  _MILES MILES AND EVACUATE THE FOLLOWI                  ECTORS FROM

[ 1 N [ 1 S W [ 1 NNE [ 1 SSW [ 1 NE SE [ 1 SW [ 1 ENE SSE [ 1 WSW AND _ _ _ IVIILES The utility recom that government officials notify the general public to assium iodide (KI) for those areas where 0 the EPZ to monitor EAS Messages. [ 1 _ _ _ MILES The utility rec s that government officials notify the general public otassium iodide tOIio~fSe areas where evacuation is recommended and advise remainder of ttl monitor EAS Messages.

8. CONCLUSION: [X 1This is a DRILL. [ 1This is an ACTUAL EVENT.
  • PERFORM FINAL ROLL CALL UPON COMPLETION .- Refer to Page 3 of Form
  • ASK if there are any questions regarding message or repeat backs needed
  • READ "This concludes the notification message"
  • FAX completed copies of all form pages to the Control Room, TSC and EOF, as applicable.
  • INFORM the Shift Manager (Shift Emergency Director), TSC Director or EOF Director, as applicable, when notification is completed to required contacts.

Document Retention SRRS-ID - 58.100

EP-MA-114-100-F-01 Revision G Page 3 of 3 STATE/LOCAL EVENT NOrlFICATION FORM "15 Minute Notifications" "15 Minute Notifications" PEACH BOTTOM (CAN 833) LIMERICK (CAN 841) 

  "Notification Line": Dial "833" for conference call. Stay on the line until agencies come on                                         Initial Roll Call                            Final Roll Call "3 Digit Extensions. Make these calls from 3-digit lines.        (Time Contacted: 24-hour clock)                          (",f)
  "Commercial # From PBAPS": Make these calls from a 4-digit line. Dial "9-1-Area Code-Number"                                                      Pennsylvania EMA                  D "Commercial # From PBABS 3-digit lines: Dial"7-1-9-1-Area                     Ext. 116 or 9-1-800-424-7362 or Code-Number" 9-1-717 -651-2001 Initial Roll Call                           Final Roll Call (Time Contacted: 24-hour clock)                      (~

Montgomery County D Ext. 117 or 9-1-610-631-6541 Pennsylvania EMA Chester County D Ext. 216 or 9-1-800-424-7362/ Ext. 118 or 9-1-610-344-5100 9-1-717-651-2001 Maryland EMA D Berks County D Ext. 119 or 9-1-61 0-655-4931 Ext. 205 or 9-1-410-517-3600 Initial Roll Call Completed York County "15 Minute Notifications" Ext. 219 or 9-1-717-854-5571 TMI (CAN 44) Harford County "Notification Line": Dial "44" for all-call. If necessary, dial 3-digit extension #'s to notify individual agencies Ext. 214 or 9-1-41 0-638-3400 / Commercial # From TMI: Dial "9" and the # 9-1-410-638-4900 Commercial # From EOF: Dial "9-1-717" and the # Cecil County Toll-Free "800" # From TMI or EOF: Dial the #'s exactly as they appear below Ext. 234 or 9-1-410-398-2222 / Initial Roll Call Final Roll Call 9-1-410-392-2010 (Time Contacted: 24-hour clock) (.,j) Lancaster County Pennsylvania EMA D Ext. 315 or 9-1-800-424-7362 or Ext. 217 or 9-1-800-808-5236 / 9-651-2001 9-1-717-664-1190 Cumberland County D Chester County Ext. 319 or 9-238-9676,9-243-4121 or 9-532-8878 Ext. 218 or 9-1-61 0-344-51 00 Lebanon County D Initial Roll Call Completed Ext. 321 or 9-272-2025 / -7621 / -2054 Lancaster County D Ext. 318 or 9-664-1190 / -1200 FOLLOW-UP NOTIFICATIONS * (PEACH BOTTOM ONLY) York County D Ext. 317 or 9-854-5571, 9-840-2955 or [ ] Maryland Dept. of the Environment 9-1-800-427 -834 7 Emergency ext. 292 or 235 Dauphin County D 9-1-866-633-4686 Ext. 320 or 9-911 or 9-558-6900 Contacted at: (time: 24-hour clock) Initial Roll Call Completed [ ] PA State Police, York Barracks FOLLOW-UP NOTIFICATIONS * (TMI) Ext. 284 or 9-1-717-428-1011 [ ] York Haven Power Station Contact~d at: (time: 24-hour clock) 9-266-3654 or 9-818-3962 Contacted at: (time: 24-hour clock) .. NOT required within 15 minutes of Classification Document Retention SRRS-ID - 58,100

Exel n EP-MA-114-100-F-01 Revision G Nuclear Page 1 of 3 STATE/LOCAL EVENT NOTIFICATION FORM UTILITY MESSAGE NO. 1 EMERGENCY DIRECTOR APPROVAL: Jim Jones PERFORM INITIAL ROLL CALL PRIOR TO TRANSMITTING - Refer to Page 3 of Form

1. CALL STATUS is: 2. This is _ _ _ _ _ _ _ _ _ _ _ __ _

[[X] X] This is a DRILL. for [ 1LIMERICK / [X 1PEACH BOTTOM / [ ] TMI [ ] This is an ACTUAL EVENT. My phone number is The cu [Communicator will provide his/her NAME, PHONE NU TIME (in 24-hour clock) when notification is read] 3.a EMERGENCY CLASSIFICATION b. AFFECTED UNIT(S) is/are: [ 1UNUSUAL EVENT [ ] ONE [Xl TWO [ ] THREE DECLARATION [X] ALERT LATION [ 1SITE AREA EMERGENCY c. DECLARED AT: [ ]GENERALEMERGENCY [ ] RECOVERY -IN CLASSIFICATION STATUS DATE: --'-=~=; [ ] TERMINATION

4. a. EMERGENCY ACTION LEVEL lEAL} NO. is:

failed to automatically when required. Current plant threaten public safety. radiological release in-progress aOlClloOI'cal release TERMINATED

a. WIND DIRECTION is FROM: _ _---.:.1..:;5 ---.:.1..:;5___

___ (degrees)

b. WIND SPEED is: _ _---'-1=2~___ (miles per hour)

ANSWER KEY - DO NOT HAND OUT TO CANDIDATES Document Retention SRRS-ID-5B.100

EP-MA-114-100-F-01 Revision G Page 2 of 3 STATE/LOCAL EVENT NOTIFICATION FORM

7. UTILITY PROTECTIVE ACTION RECOMMENDATION.: (a or b) - No action should be taken until government officials have been notified: by State:

[X ] a NOT APPLICABLE (Unusual Event, Alert, Site Area Emergency, Tennination or Recovery only) - ---(Complete the fol/owing for Shelter or Evacuation for a General Emergency only for the applicable station): 1b. The PROTECTIVE ACTION RECOMMENDATION (PAR) from the utility is: SHELTER 360 DEGREES FROM 0 MILES (SITE BOUNDARY) TO _ _ _ _._._ SH THE FOLLOWING SECTORS FHOM [ ] [ ] E [ ] S [ ] NNE [ ] ESE [ ] SSW [ ] NE [ ] SE [ ] SW [ ] ENE ] [ ] WSW AND The utility recommends that 9 to take potassium iodide en (KI) for those sectors where shelter of the EPZ to monitor 0 0-ct EAS Messages. m 0 0-en (!) 

   ...J

[ ] EVACUATE 360 DEGREES FROM 0 AND MILES EVACUATE THE [ ] N W [ ] NNE SSW [ ] NE SW [ ] ENE WSW AND i I I- [ 1This is an ACTUAL EVENT. PERFORM FINAL ROLL CALL UPON COMPLETION .- Refer to Page 3 of Form

  • ASK if there are any questions regarding message or repeat backs needed
  • READ "This concludes the notification message"
  • FAX completed copies of all form pages to the Control Room, TSC and EOF, as applicable.
  • INFORM the Shift Manager (Shift Emergency Director), TSC Director or EOF Director, as applicable, when notification is completed to required contacts.

ANSWER KEY - DO NOT HAND OUT TO CANDIDATES Document Retention SRRS-ID - 5B.1 00

EP-MA-114-100-F-01 Revision G Page 3 of 3 STATE/LOCAL EVENT NOTIFICATION FORM "15 Minute Notifications" "15 Minute Notifications" PEACH BOTTOM (CAN 833) LIMERICK (CAN 841) 

   "Notification Line": Dial "833" for conference call. Stay on the line until agencies come on                                         Initial Roll Call                            Final Roll Call "3 Digit Extensions. Make these calls from 3-digit lines.        (Time Contacted: 24-hour clock)                           (..J)
   "Commercial # From PBAPS": Make these calls from a 4-digit line. Dial "9-1-Area Code-Number"                                                     Pennsylvania EMA "Commercial # From PBABS 3-digit lines: Dial "7-1-9-1-Area                    Ext. 116 or 9-1-800-424-736 Code-Number" 9-1-717 -651-2001 Initial Roll Call                           Final Roll Call (Time Contacted: 24-hour clock)                      (..J)                            Montgomery Ext. 11 7 or 9-1-6 Pennsylvania EMA                  D Ext. 216 or 9-1-800-424-7362 /

ChO'c:t'tO D 100 9-1-717 -651-2001 Maryland EMA D nty D 

                                                                                                      -610-655-4931 Ext. 205 or 9-1-410-517-3600 York County                   D inute Notifications" Ext. 219 or 9-1-717-854-5571 Harford County                 D                                n Line": Dial "44" for all-call. If necessary, Ext. 214 or 9-1-410-638-3400 /                                git extension #'s to notify individual agencies mercial # From TMI: Dial "9" and the #

9-1-410-638-4900 Cecil County D Toll-Free "800" # From TMI or EOF: Dial the #'s exactly as they appear below Ext. 234 or 9-1-410-398-2222 / Initial Roll Call Final Roll Call 9-1-410-392-2010 (Time Contacted: 24-hour clock) (..J) Lancaster County Pennsylvania EMA D Ext. 315 or 9-1-800-424-7362 or 9-651-2001 9-1-717 -664-1 Cumberland County D Chester Co Ext. 319 or 9-238-9676, 9-243-4121 or 9-532-8878 Lebanon County D leted Ext. 321 or 9-272-2025 / -7621 / -2054 Lancaster County D Ext. 318 or 9-664-1190 / -1200 FICATIONS

  • BOTTOM ON York County D Ext. 317 or 9-854-5571, 9-840-2955 or Dept. of the Environment 9-1-800-427 -834 7 mergency ext. 292 or 235 Dauphin County D 9-1-866-633-4686 Ext. 320 or 9-911 or 9-558-6900 (time: 24-hour clock) Initial Roll Call Completed

[ ] PA State Police, York Barracks FOLLOW-UP NOTIFICATIONS * (TMI) Ext. 284 or 9-1-717-428-1011 [ ] York Haven Power Station Contacted at: (time: 24-hour clock) 9-266-3654 or 9-818-3962 Contacted at: (time: 24-hour clock)

  • NOT required within 15 minutes of Classification ANSWER KEY - DO NOT HAND OUT TO CANDIDATES Document Retention SRRS-ID - 58.100

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET D QUALIFICATION MANUAL OJT MODULE Licensed Operator Training PLOR-340CA Licensed Operator Requalification 000 J. A. Verbillis jav Evaluation of High CRD Temperature on Control Rod Scram Time (SRO) APPROVALS: Signature I Tille Date Signature I Title Date Signature APPROVED FOR USE: 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 PLOR340CA RevOOO Page 1 of 5

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Senior Reactor Operator TASK-JPM DESIGNATOR: 20110504021 PLOR-340CA 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" . .IPMIPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
b. When performing "In-Plant" . .IPMs, IPMs, 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 . .IPM, IPM, though listed in the task standard, is not to be given to the examinee.

PLOR340CA RevOOO Page 2 of 5

B. TOOLS AND EQUIPMENT

1. AO 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time"
2. Calculator
3. Tech Spec 3.1.3, 3.1.4 and Bases C. REFERENCES
1. AO 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time"
2. Tech Spec 3.1.3, 3.1.4 and Bases D. TASK STANDARD
1. Satisfactory task completion is indicated when Control Rod 18-55 is declared SLOW 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. Control Rod 18-55 temperature is 405 of and cannot be lowered.
3. System Manager has provided the latest Scram Time data for CR 18-55:

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

4. There are no control rods currently declared slow.
5. AO 3.8 has been completed up through Step 4.7, including Attachment 1.

G. 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. (HAND THE SRO CANDIDATE THE IN-PROGRESS COPY OF AO 3.8 WITH ATTACHMENT 1 COMPLETE THROUGH THE IV.) PLOR340CA RevOOO Page 3 of 5

H. PERFORMANCE CHECKLIST II 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. 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 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.
                                               **** NOTE: ****

Station expectation is to identify and document Potential TSA for TS 3.1.4. This is NOT critical. 5 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) 6 Notify System Manager of status of P System Manager notified Control Rod 18-55 (Cue: As System Manager, acknowledge report) 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 procedures. Under "ACT" P - must perform S - must simulate PLOR340CA RevOOO

L TERMINATING CUE When Control Rod 18-55 is declared SLOW and AO 3.8 is complete, the evaluator will terminate the exercise. PLOR340CA RevOOO Page 5 of 5

TASK CONDITIONS/PREREQUISITES

1. Unit 3 is at 100% power.
2. Control Rod 18-55 temperature is 405 of and cannot be lowered.
3. System Manager has provided the latest Scram Time data for CR 18-55:

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

4. There are no control rods currently declared slow.
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.

AO 3.8 Rev. 0 Page 1 of 9 NHN:nhn Exelon Nuclear Bottom Units 2 3 EVALUATION OF HIGH CRD TEMPERATURE ON CONTROL ROD SCRAM TIME PURPOSE This procedure provides the ruct necessary to evaluate the impact of high CRD hydraulic temperature on control rod scram 

           'me, as recommended by GE SILs 173 and 173S1, to ensure compliance with Technical Speci             ions 3.1.3 and 3.1.4.

temperature has reached OR exceeded 350°F. igh CRD hydraulic temperature may result in t associated control rod being decl slow in accordance with Te cal Specification 3.1.4. Technical Specifications 3.1.3 AND 3.1.4 should be reviewed when this procedure is entered_ PERFORMANCE STEPS NOTES scram t s for Pos ions 46, 36, 26, and 06 for control rod will obtained from cop s located the em Status les of last rformance either ST*-R-003-475-2(3) , ST-R-003-485-2(3) or ST-R-003-495-2(3) , OR f m control rod scram time database located on computer '----..J'V-L_ve S: \Scram Time\scramtime.mdb. T e last rformance of ST-R-003-475-2(3) , ST-R-003-485 2(3), or T-R-003-495-2(3) is reviewed first to determine if the control rod was includeduded in scope of testing_ If so, necessa scram t s will be obtained from this source the control rod scram time database may not have been updated ~o reflect the latest scram time data. IF the associated control rod was NOT included in the scope of testing the last performance of ST-R-003-475 2(3), ST--R-003-485-2 (3), or ST-R-003-495-2 (3), THEN necessary cram times will be obta from the control rod scram t database. 1, "Control Rod Scram Time Impact Calculation", will a to document performance of this procedure. IF CRD hydraulic temperature can not be lowered below 350 0 F, THEN RECORD the associated Unit, control rod number

AO 3.8 Rev. 0 2 of 9 hydraulic temperature on Attachment 1 s 6, 7, 8, the control rod scram times for positions 46, 36, 26, for the associated control as follows: 1.0 IF the control rod was scram t in the last formance of ST-R-003-475-2(3), ST-R-003 485-2(3) OR 1V/~ ST-R-003-495-2(3) during the current operating cycle, THEN RECORD the control rod scram times documented in Surveil Test in the appropriate location in Attachment 1 6, 7, 8, 9. 2.0 IF the control rod was NOT t in the last performance o the Surveillance Tests in the previous step, THEN 1V/~ OBTAiN the latest cont~ol rod scram times during the current operat cycle from control rod scram time dat se located on computer dr S:\Scram T \scramtime.mdb AND RECORD in the appropriate location in Attachment 1 pages 6, 7, 8, and 9. 

   ~F         the control rod scram time    r the current
 ~cle could not                obtained by one of the steps, THEN CONTACT Enqineering AND OBTAIN the latest control rod scram times during t      current     rating cycle AND RECORD in the appropriate location in

(\ Attachment 1 6, 7, 8, 9. ~ETERMINE the Position 46(36, 26, 06) Penalty using Tab 1(2, 3, 4) on page 6(7, 8, 9) AND RECORD in the appropriate location in Attachment 1. ~nD Position 46(36, 26, 06) control rod scram time to ~the Position 46(36, 26, 06) penalty to determine the temperature corrected Position 46(36, 26, 06) cont rod scram time AND RECORD in the appropriate location Attachment 1. ~~~CORD the Maximum Notch 46(36, 26, 06) Scram T lowed ~~ Tech Spec Table 3.1.4-1 in the appropriate location in Attachment 1. ~IRECT that an Independent Veri cation be per for all ~ntries on Attachment 1 AND DOCUMENT in the appropriate location in Attachment 1.

AO 3.8 Rev. 0 Page 3 of 9 

  ~~DIRECT         Reactor Engineering to                 ST-R-003-480-2(3),
  ~      "Average Scram Time For ODYN/B                    Criti       Power Ratio (MCPR) requirements," within 72 hours.

Person Contacted: ?R'l tE. 9danager Time: lili:mm Date: 'Totlay's (])ate 4.8 DETERMINE if the temperature corrected Position 46(36, 26,

06) control rod scram time is r Maximum Notch 46(36, 26, 06) Scram Time lowed by Tech Spec Table 3.1.4 1.

1.0 IF ALL temperature cor:cected control rod scram times are less than OR equal to Maximum Notch Scram Time allowed by Tech Spec Table 3.1.4-1, THEN GO to Step 4.11. OTHERWISE, N/A. 2.0 IF ANY temperature corrected control rod scram time is greater than the Maximum Notch Scram allowed by Tech Spec Table 3.1.4 1, THEN GO to St 4.9. OTHERWISE, N/A. 4.9 IF ANY temperature corrected control rod scram time is greater than the Maximum Notch Scram allowed by Tech Spec Table 3.1. 4-1, THEN D:ECLARE control rod "slow" AND COMPLY with Technical Speci cations 3.1.3 AND 3.1.4. OTHERWISE, N/A. 4.10 IF ANY control rod scram t is than 7 seconds to notch position 06, THEN DECLARE control rod inoperable AND COMPLY with Technical ficat 3.1.3. OTHERWISE, N/A. CAUTIONS

1. In accordance with Technical Specification 3.1.4, combinations of "slow" control re a plant shutdown.

The intent of the following step is to ensure any temperature correction for a control rod that has POTENTIAL to require a plant shutdown is verified since a plant shutdown either will be, or will not be, Performed based on the ation.

2. The following step is hot intended to re performance of a plant shutdown if required by cal ion 3.1.4.

4.11 REGARDLESS of whether or not the rod was evaluated as slow, IF the control rod is adjacent "slow" control rod OR IF 12 other control rods been declared

AO 3.8 Rev. 0 Page 4 of 9 "slow", THEN U1MEDIATELY NOTIFY the EDM AND DIRECT that neering IMMEDIATELY verify the accuracy of the corrected control rod scram time calculation. OTHERWISE, N/A. 4.12 DOCUMENT i Management review of Attachment 1. 4.13 INITIATE an Issue to correct the high CRD temperature condition. 4.14 NOTIFY t CRD System Manaqer that AO 3.8 has been per AND FORWARD Attachment 1 to the System Manager.

AO 3.8 Rev. 0 5 of 9 5.0 CONTROL STATIONS 5.1 None

6. 0 RE~ERENCES 6.1 GE SIL 173 6.2 GE SIL 173S1, Revision 1 7.0 TECHNICAL SPECIFICATIONS 7.1 3.1.3 7.2 3.1.4 8.0 INTERFACING PROCEDURES 8.1 ARC 2(3)11 G-5, "CRD Hydraulic Hi Temp" 8.2 ST-R-003-475-2(3), "CRD Scram Insertion Timing Following Reactor Scram" 8.3 ST-R-003-485 2(3), "CRD Scram Insertion Timing of Selected Control Rods" 8.4 ST-R-003-495 2(3), "CRD Scram Insertion Timing of Select Control Rods During Hydro"

AO 3.8 Rev. 0 Page 6 of 9 : Control Rod Scram Time Calculation Initial Date

.----------------------------------~----------------

(Step 4.1) Unit: 3 Associated control rod: 18-55 VfR,O !loaay Record the CRD Temperature: VfR,O !loaay Position 46 Scram Time Penalt Calculat (Step 4.2) Posit 46 Scram Time: 0.343 sec VfR,O !loaay (St 4.3 ) Position 46 Penalty (from Table 1 low) : 0.35 sec VfR,O !loaay (Step 4.4) Determine the rature Corrected Position 46 Control Rod Scram Time by adding the Position 46 Scram Time and Position 46 Penalty: 0.693 sec VfR,O !loaay (Step 4.5) Maximum Notch Position 46 Scram Time allowed by Tech Spec Table 3.1.4 1: 0.44 sec VfR,O !loaay Table 1: GE SIL 173 Position 46 Penalty 1 CRD Temp Pos ion 46 Penalty 

                    > 350 0 F and < 400 0 F      0.07 sec 400 0 F            0.35 sec (Step 4.6) Pos ion 46 temperature corrected Control Rod Scram Time Independent Veri               ion     rmed by:        111lL/I'otfay
1. V.

AO 3.8 Rev. 0 7 of 9 : Control Rod Scram T Date (Step 4.1) Unit: 3 Associated control rod: 18-55 VfRQ!Ioaay Eecord the CRD rature: VfRQ!Ioaay Position 36 Scram Time Pena Calculation ion (Step 4.2) Pos 36 Scram T 0.844 sec VfRQ!Ioaay (Step 44.3) 

       .3)  Position 36 Penalty (from Table 2 below):                               0.60     sec VfRO!foaay (Step 4.4) Determine the Temperature Correct     Position 36 Control           Scram Time by adding the Pos ion 36 Scram Time and Position 36 Penalty:                       1. 444 sec   VfRO!Ioaay (Step 4.5) Maximum Notch Position 36 Scram Time allowed by Tech Spec        e 3.1.4 1:                         1. 08  sec   VfRO!foaay Table 2: GE SIL 173 Position 36 Penalty CRD Temp             Pos ion 36 I                                  Penalty
                    -> 350 0 F and < 400 0 F        0.14 sec
                             > 400 0 F
                                                !   0.60 sec (Step 4.6) Position 36 temperature corrected Control Rod Scram T       Independent Verification performed by:          I1Jq(JI'otfay I.V.

AO 3.8 Rev. 0 Page 8 of 9 : Control Rod Scram Time ct Calculation Initial Date (S 4.1) Unit: 3 Associated control rod: 18 55 ViP lToaay Position 26 Scram Time Penalt tion ( S t e p 4. 2 ) Po sit ion 2 6 SScram cram 1.396 sec ViP lToaay (Step 4.3) Position 26 Penalty (from Table 3 below): 0.70 sec ViP lToaay (Step 4.4) Determine the Temperature Correct Pos ion 26 Control Rod Scram Time by adding t Posit 26 Scram and Position 26 Penalty: 2.096 sec ViP lToaay (Step 4.5) Maximum Notch Pos ion 26 Scram Time allowed by Tech Spec Table 3.1.4-1: 1. 83 sec ViP lToaay Table 3: GE SIL 173 Position 26 Penalty CRD Temp Position 26 Penalty 350 0 F and < 400 0 F 0.17 sec 

                                  > 400 0 F            0.70 sec (S        4.6)    Position 26 temperature corrected Control Rod Scram              Independent Verification performed by:            11AJLITod'ay
1. V.

AO 3.8 Rev. 0 Page 9 of 9 : Control Rod Scram T Calculation Initial Date

~---------,-----~--------~----------------

(Step 4.1) Unit: 3 Associated control rod: 18-55 VfRO /today Record the CRD Temperature: VfRO /today Positio~ 06 Scram Time lculation (Step 4.2) Position 06 Scram Time: 2.599 sec VfRO /today (St 4.3) Position 06 Penalty (from Table 4 low) : 0.70 sec VfRO /today (Step 4.4) Determine the Temperature Corrected Position 06 Control Rod Scram Time by adding the Position 06 Scram Time and Position 06 Penalty: 3.299 sec VfRO /today (Step 4.5) Maximum Notch Position 06 Scram Time allowed by Tech Spec Tab 3.1.4-1: 3.35 sec VfRO /Today Table 4: GE SIL 173 Position 06 Penalty CRD Temp Position 06 Penalty 

                  > 350 0 F and < 400 0 F 0.15 sec
                          > 400 0 F            0.70 sec (Step 4.6) Position 06 temperature corrected Control Rod Scram Time Independent Verification performed by:             Io/ClLlI'oaay
1. V.

(Step 4.12) Shift Management review of Attachment 1 pages 6, 7, 8, and 9 performed by:

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET ommon JPM D QUALIFICATION MANUAL OJT MODULE Licensed Operator Training Licensed Operator Requalification Compliance with Asymmetric Feedwater Heating Operation (AFTO) - SRO Version APPROVALS: Signature I Title Date APPROVED FOR USE: EFFECTIVE DATE: _ _ _,, 1_ 1___ _..1_ _ NAME: ISSUE DATE: Last First M.1. EMPLOYEE 1.0. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: Signature/Date PLQR252C Rev002

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Senior Reactor Operator TASK-JPM DESIGNATOR: 25903604021 PLOR-252C KIA: G2.1.7 SRO: 4.7 TASK DESCRIPTION: Asymmetric Feedwater Temperature Operation (AFTO) 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 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.

PLOR252C Rev002

B. TOOLS AND EQUIPMENT

1. AO 6.7-2 "Asymmetric Feedwater Temperature Operation (AFTO)"
2. RE-41 "lnstaliationNerification of the 3D Monicore Thermal Operating Limits"
3. Calculator
4. Technical Specification 3.2
5. PLOR252C At 2 - Prepared RE-41 Attachment 1 C. REFERENCES
1. AO 6.7-2, Rev. 6 "Asymmetric Feedwater Temperature Operation (AFTO)"
2. RE - 41, Rev. 9 "lnstaliationNerification of the 3D Monicore Thermal Operating Limits" D. TASK STANDARD
1. Satisfactory task completion is indicated when steps 1.1 through 2.3.3 of Attachment 2 of AO 6.7-2, Asymmetric Feedwater Temperature Operation (AFTO). are properly completed.
2. Estimated time to complete: 20 minute:s Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to assure compliance with regulations during asymmetric feedwater temperature operation 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 was at 100% power when it experienced a loss of feedwater heating.
2. OT-104 "Positive Reactivity Insertion" was entered and reactor power was lowered to 89% power and is presently stable.
3. It was determined that feedwater heating is asymmetric and procedure AO 6.7-2 "Asymmetric Feedwater Temperature Operation (AFTO)" was entered.
4. PMS Computer point NSS018 is INVALID.
5. All reactor feedwater pumps are in service.
6. Feedwater temperatures as read on TR-2151 are as follows:
            'A' feedwater temperature = 325 degrees F
            'B' feedwater temperature =325 degrees F
            'C' feedwater temperature = 300 degrees F PLOR252C Rev002                                                                           Page 3 of 8

G. INITIATING CUE The Control Room Supervisor directs you, an extra SRO on shift, to perform Attachment 2, "Feedwater Temperature Reduction Monitoring Requirements" of AO 6.7-2 "Asymmetric Feedwater Temperature Operation". PLOR252C Rev002 Page 4 of 8

H. PERFORMANCE CHECKLIST II STEP STEP ACT STANDARD NO 1 Obtain a copy of AO 6.7-2. P AO 6.7-2 "Asymmetric Feedwater Temperature Operation (AFTO)" is (Cue: Provide a copy of AO 6.7-2, and obtained. prepared copy of PLOR252C AT 2 - RE- RE 41, Att 1, indicating that 55 of feedwater AO 6.7-2, Attachment 2, "Feedwater temperature reduction IS allowed and 90 Temperature Reduction Monitoring of Feedwater temperature reduction is Requirements", is referenced. NOT allowed) (Cue: Ensure copy of RE-41 and Tech Spec Sec 3.2 is available for candidate to reference on request) 2 Determine that second bullet of step 1.1 of P Determine that average feedwater Attachment 2 of AO 6.7-2 is applicable temperature has to be calculated using since PMS Computer point NSS018 is Attachment 2 Exhibit 1 of AO 6.7-2. INVALID. Sign-off Attachment 2 Exhibit 1. (Cue: If necessary, repeat Task/Prerequisite Condition that PMS Mark first part of step 1.1 of Attachment 2 Computer point NSS018 is INVALID.) of AO 6.7-2 as "N/A". 

    *3    Calculate average feedwater temperature       P  Since PMS Computer point NSS018 is value using Attachment 2 Exhibit 1               INVALID, per step 1.1 of AO 6.7-2 the "Determining Feedwater Injection                 Examinee will use Attachment 2 Exhibit 1 Temperature Using TR-2151 ".                     "Determining Feedwater Injection Temperature Using TR-2151" to calculate (Cue: If necessary, repeat                      the average feedwater temperature value.

Task/Prerequisite Conditions that: Examinee inserts values of 325, 325 and A FVV temperature = 325 degrees F 300 degrees F respectively into Exhibit 1. B FW temperature = 325 degrees F C FW temperature = 300 degrees F, The average feedwater injection temperature with 3 in-service reactor and that all reactor feedwater pumps are feedwater pumps is determined to be in service.) 316.6 degrees F. 4 Determine that 55 of feedwater P Candidate references RE-41 , Att 1 to temperature reduction is applicable by determine that 55 of feedwater reviewing RE-41 , Att 1 temperature reduction IS allowed. 5 Identify that Section 2.0 (of Att 2) IS P Candidate identifies Section 2.0 of Att 2 is applicable applicable (See step 1.2) II PLOR252C Rev002 Page 5 of 8

STEP STEP ACT STANDARD NO 6 Identify that Section 3.0 (of Att 2) IS NOT P Candidate identifies Section 3.0 of Att 2 is applicable NOT applicable (See step 1.2) 

 *7   Determine that Unit 2 is operating in the    P  Compare the feedwater temperature TSA Region of Attachment 2, Figure 1            determined above (316.6 degrees F)
      "Feedwater Temperature Limits"                  against the Feedwater Temperature Reduction Region Curve located on (Cue: If necessary, repeat                      Attachment 2, Figure 1 "Feedwater Task/Prerequisite Condition that Unit 2 is      Temperature Limits" of AO 6.7-2.

at 89% reactor power and stable.) Examinee should plot 316.6 degrees F at 3127 MWth (0.89 times 3514 MWth) on Attachment 2, Figure 1. 8 Notify Shift Management and Reactor P Notify Shift Management and the Reactor Engineering. Engineering group of being in the TSA Region of Attachment 2, Figure 1 (Cue: acknowledge communication) "Feedwater Temperature Limits" either face-to-face or by telephone. 

 *9    Enter the required actions for Technical    P  As required by AO 6.7-2, Attachment 2, Specification LCOs 3.2.1, 3.2.2, 3.2.3          "Feedwater Temperature Reduction Monitoring Requirements", step 1.4.2, (Cue: Provide TS 3.2 to candidate on           Tech. Spec. LCOs 3.2.1, 3.2.2, 3.2.3 are request. Acknowledge entry into the            entered. All three LCOs require that LCOs)                                           thermal limits (APLHGR, MCPR, and LHGR) are restored within 2 hours. If not restored within 2 hours, reduce thermal power < 25% within 4 hours.

PLOR252C Rev002

STEP STEP ACT STANDARD NO 10 Recognize that within the 2 hour Tech. P NOTE: step 2.3.3 of AO 6.7-2, Spec. limit, restore feedwater temperature Attachment 2 is a recognition step ONLY by either: and cannot be performed for the purposes of this JPM Returning isolated feedwater heaters to service using AO 1E.2-2 "Placing AO 6.7-2, Attachment 2, "Feedwater Feedwater Heaters In-Service after A Temperature Reduction Monitoring Heater Isolation", Requirements", step 1.4.3, requires performance of returning isolated feedwater heaters to service using AO 1 E.2-2 "Placing Feedwater Heaters In-Service after A Heater Isolation", OR OR Isolating any non-symmetric feedwater Isolating any non-symmetric feedwater heater string using AO 5.6-2 "Removing heater string using AO 5.6-2 "Removing And Restoring A Feedwater Heater String And Restoring A Feedwater Heater String To Service". To Service", due to being in the TSA Region of Attachment 2, Figure 1 "Feedwater Temperature Limits. OR Reduce reactor power to less thatn 25% RTP within the Tech Spec time limit (Cue: acknowledge required actions) 11 Inform Control Room Supervisor of P Control room Supervisor is notified of task completion of Attachment 2 "Feedwater completion. Temperature Reduction Monitoring Requirements" of AO 6.7-2. (Cue: acknowledge communication.) 12 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 PLOR252C Rev002

I. TERMINATING CUE When steps 1.1 through 2.3.2 of Attachment 2, "Feedwater Temperature Reduction Monitoring Requirements", of AD 6.7-2 are completed and it is recognized that step 2.3.3 needs to be performed, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR252C Rev002 Page 8 of 8

TASK CONDITIONS/PREREQUISITES

1. Unit 2 was at 100% power when it experienced a loss of feedwater heating.
2. OT-104 "Positive Reactivity Insertion" was entered and reactor power was lowered to 89% power and is presently stable.
3. It was determined that feedwater heating is asymmetric and procedure AO 6.7-2 "Asymmetric Feedwater Temperature Operation (AFTO)" was entered.
4. PMS Computer point NSS018 is INVALID.
5. All reactor feedwater pumps are in service.
6. Feedwater temperatures as read on TR-2151 are as follows:
                              =

A feedwater temperature 325 degrees F 

                              =

B feedwater temperature 325 degrees F C feedwater temperature = 300 degrees F INITIATING CUE The Control Room Supervisor directs you, an extra SRO on shift, to perform Attachment 2, "Feedwater Temperature Reduction Requirements" of AO 6.7-2, "Asymmetric Feedwater Temperature Operation".

RE-41 Rev. 9 Page 9 of 9 ATTACHMENT 1 3D Monicore Installed Thermal s (Check one column for ea Operational Condition) Unit 2 Operational tion ALLOWED NOT ALLOWED (Thermal ing (Thermal ing Limits Implemented Limits NOT lemented AND operation OR operation not a owed at this a owed at this t in time in the cycle) the cycle) Increased Core Flow (>100% to ~110% of rated) 55° Feedwater rature Reduction 90° Feedwater Temperature Reduction Prepared IV: Otlier~ CEng 

               ~ CEng    /  tToday                                 /  tToday By /Date                              By /Date

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET h Bottom Comm 

              ~      JPM               D      QUALIFICATION MANUAL            D  OJT MODULE LICENSED OPERATOR TRAINING                                          PLOR-242C LICENSED OPERATOR REQUALIFICATION                                  001 M. J. Kelly                                                        jav DE:TERMINATION OF REQUIRED POST-MAINTENANCE TESTING APPROVALS:

Signature / Title Date Signature / Title Date APPROVED FOR USE: Signature / Title Date EFFECTIVE DATE: _ _ _ < _ _ _ _< NAME: ISSUE DATE: Last First M<I. EMPLOYEE ID NO. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: Signature/Date PLOR242C Rev001 Page 1 of 7

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Senior Reactor Operator TASK-JPM DESIGNATOR: 29801902011 PLOR-242C KIA: G2.2.21 SRO: 3.5 TASK DESCRIPTION: Determination of Required Post-Maintenance Testing 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 slJccessful 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" ....IPMs IPMs are designed to be performed in the simulator. If a "Control Room" ....IPM 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.

PLOR242C Rev001 Page 2 of?

B. TOOLS AND EQUIPMENT

1. MA-AA-716-012 "Post Maintenance THsting"
2. RT-O-023-725-2 "HPCI Response Time Test"
3. RT-O-023-750-2 "HPCI Functional Test From Alternative Control Panels"
4. RT-O-023-760-2 "HPCI Valve and Component Test from Alternative Control Panel"
5. RT-O-023-770-2 "Alternative Control Panel Power Supplies And Logic Relays Check"
6. ST-O-023-301-2 "HPCI Pump, Valve, Flow and Unit Cooler Functional and In-Service Test"
7. ST-O-023-350-2 "HPCI Valve Alignment and Filled and Vented Verification"
8. ST-O-023-501-2 "HPCI Valves Remote Position Indication Verification"
9. ST-O-023-611-2 "HPCI system Piping Pressure Test Inspection"
10. ST-O-023-700-2 "HPCI Contaminated Piping Inspection"
11. ST-O-094-400-2 "Stroke Time Testing of Valves for Post Maintenance Testing"
12. Attachment 2 of this JPM "PIMS 1ST Pump and Valve Testing Data" C. REFERENCES
1. MA-AA-716-012, Rev. 011 ,"Post Maintenance Testing"
2. ST-O-023-301-2, Rev. 052, "HPCI Pump, Valve, Flow and Unit Cooler Functional and In-Service Test"
3. ST-O-023-501-2, Rev. 008. "HPCI Valves Remote Position Indication Verification"
4. ST-O-094-400-2, Rev. 002, "Stroke Time Testing of Valves for Post Maintenance Testing" D. TASK STANDARD
1. Satisfactory task completion is indicated when the appropriate post maintenance testing requirements for AO-2-23-40, and the associated surveillance test performance steps which are required to be performed, are determined.
2. Estimated time to complete: 20 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to determine post maintenance testing requirements using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.

PLOR242C Rev001 Page 3 of 7

F. TASK CONDITIONS/PREREQUISITES Limit switch adjustments are planned for AO-2-23-40 "HPCI Gland Seal Condensate Pump Outboard Discharge Isolation Valve to Radwaste." G. INITIATING CUE The Shift Manager directs you, as WECS, to determine post maintenance testing requirements for AO-2-23-40 "HPCI Gland Seal Condensate Pump Outboard Discharge Isolation Valve to Radwaste," using MA-AA-716-012, "Post Maintenance Testing," and circle required steps of procedures. Partial Procedure development is NOT required. PLOR242C Rev001 Page 4 of7

H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD CUE: Provide the candidate with the following:

  • PIMS 1ST Pump and Valve Testing Data (Attachment 2 of this JPM).
  • MA-AA-716-012 "Post Maintenance Testing"
  • RT-0-023-725-2 RT 023-725-2 "HPCI Response Time Test"
  • RT 023-750-2 "HPCI Functional Test From Alternative Control Panels"
  • RT-0-023-760-2 "HPCI Valve and Component Test from Alternative Control Panel"
  • RT-0-023-770-2 "Alternative Control Panel Power Supplies And Logic Relays Check"
  • ST-O-023-301-2 "HPCI Pump, Valve, Flow and Unit Cooler Functional and In-Service Test"
  • ST 023-350-2 "HPCI Valve Alignment and Filled and Vented Verification"
  • ST 023-501-2 "HPCI Valves Remote Position Indication Verification"
  • ST-0-023-611-2 "HPCI system Piping Pressure Test Inspection"
  • ST-0-023-700-2 "HPCI Contaminated Piping Inspection"
  • Have a copy of ST-0-094-400-2, Rev. 002, "Stroke Time Testing of Valves for Post Maintenance Testing" available on request (Additional tests have been included as possible distractors to the Examinee)
  *1  Determine that BOTH a Functional Stroke      PReferences MA-AA-716-012, Attachment and a Stroke Time Test are required due           3, AOV Post Maintenance Test Matrix, to limit switches being adjusted.                 (bottom of page 3 of 3).

2 Identify that ST-O-023-301-2, "HPCI P Using Attachment 2 of this JPM, PIMS Pump, Valve, Flow and Unit Cooler printout "1ST Pump and Valve Testing Functional and In-Service Test", is the Data," determines that ST-O-023-301-2 is governing 1ST Surveillance. the governing 1ST Surveillance. PLOR242C RevOO 1 Page 5 of 7

~ TEP NO STEP ACT STANDARD 

           ---------------------------~----~--------------------------~I
                                     ***NOTE TO EVALUATOR***

Step 3 below is only applicable if the Examinee decides to perform a partial of ST-O-023-301-2 as the means to document the post maintenance test of AO-2-23-40. 

 *3    Identify the following performance section   PReviews ST-0-023-301-2 and determines steps of ST-0-023-301-2, "HPCI Pump,            (circles) steps 6.1.47 or 6.1.49 and 6.1.50 Valve, Flow and Unit Cooler Functional          need to be performed, at a minimum, in and In-Service Test", need to be                order to stroke test AO-2-23-40.

performed: It is also acceptable to identify steps 6.1.47 or 6.1.49 and 6.1.50 6.1.46 through 6.1.52 to be performed as long as steps 6.1.47 or 6.1.49 and 6.1.50 are included. 

 *4    Identify the following performance section   PReviews ST-0-023-501-2 and determines steps of ST-0-023-501-2, "HPCI Valves           (circles) steps 6.2 needs to be performed, Remote Position Indication Verification",       recording results in Data Sheet 1.

need to be performed: Step 6.2 and record on Datasheet 1 

                                     ***NOTE TO EVALUATOR***

Step 4 below is only applicable if the Examinee decides to perform ST-0-094-400-2 as the means to document the post mClintenance test of AO-2-23-40. 

 *5    Identify that stroke testing in the CLOSED   PReview ST-0-094-400-2, Rev. 1. Identify direction steps of ST-0-094-400-2,              that stroke testing in the CLOSED "Stroke Time Testing of Valves for Post         direction steps will need to be performed Maintenance Testing," will need to be           for AO-2-23-40. Confirm correct stroke performed. Correctly transfer stroke time       time of 2.0 seconds is entered in step 6.5 from ST-0-023-301-2.

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. PLOR242C Rev001

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When post maintenance testing requirements for AO-2-23-40 and the associated surveillance test performance steps are determined the Shift Manager should be informed. The evaluator will then terminate the exercise. PLOR242C Rev001 Page 7 of7

TASK CONDITIONS/PREREQUISITES Limit switch adjustments are planned on AO-2-23-40 "HPCI Gland Seal Condensate Pump Outboard Discharge Isolation Valve to Radwaste." INITIATING CUE The Shift Manager directs you, as WECS, to determine post maintenance testing requirements for AO-2-23-40 "HPCI Gland Seal Condensate Pump Outboard Discharge Isolation Valve to Radwaste," using MA-AA-716-012, "Post Maintenance Testing," and circle required steps of procedures. Partial Procedure development is NOT required.

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET Peach 80 Limerick ommon I 

              ~      ....IPM IPM                    ~JUJ\LIFICATION MANUAL         D  OJT MODULE LICENSED OPERATOR TRAINING                                           PLOR-215C LICENSED OPERATOR REQUALIFICATION                                    003 J. A. Verbillis                                                     jav REVIEW AND AUTHORIZE ISSUANCE OF THYROID BLOCKING AGENT (KI)

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 NO. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: Signature/Date PLOR215C Rev003 Page 1 af6

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Senior Reactor Operator TASK-"IPM DESIGNATOR: 2007560502/ PLOR-215C KIA: G2.3.14 SRO: 3.8 TASK DESCRIPTION: REVIEW AND AUTHORIZE ISSUANCE OF THYROID BLOCKING AGENT (KI) 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.

PLOR215C Rev003 Page 2 of6

B. TOOLS AND EQUIPMENT

1. EP-AA-113, Personnel Protective Actions
2. EP-AA-113-F-03, Thyroid Blocking Agent Authorization Form completed with the exception of the Station Emergency Director authorization.
3. EP-AA-1007, Radiological Emergency Plan Annex for Peach Bottom Atomic Power Station
4. EP-AA-114-F-01, Release in Progress Determination Guidance
5. Procedure index for EP procedures.
6. Worker history descriptions.

C. REFERENCES

1. EP-AA-112-100-F-01, Rev. K, "Shift Emergency Director Checklist"
2. EP-AA-113, Rev. 10, "Personnel Protective Actions"
3. EP-AA-113-F-03, Rev. C, "Thyroid Blocking Agent Authorization"
4. EP-AA-1007, Rev 018, Radiological Emergency Plan Annex for Peach Bottom Atomic Power Station
5. EP-AA-114-F-01, Rev 0, Release in Progress Determination Guidance D. TASK STANDARD
1. Satisfactory completion of this task is indicated when the Emergency Director has reviewed and denied the issuance of Thyroid Blocking Agent.
2. Estimated time to complete: 20 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, review the information provided including the Thyroid Blocking Agent Authorization and make the decision as to whether to authorize the issuance of Thyroid Blocking Agent. I will describe the initial conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. Unit 2 experienced a LOCA transient that resulted in a Site Area Emergency declaration.
2. A small steam leak continues to exist in the Turbine Building due to failure of both Inboard and Outboard MSIVs in the B line to close.

PLOR215C Rev003 Page 30f6

3. Reactor power is 2.34 E-5% and dropping.
4. RPV level is -120 inches and steady. Lowest RPV level during the transient was -160 inches.
5. RPV pressure is 800 psig and dropping slowly.
6. Primary Containment pressure on PR-2508 is 8 psig and lowering slowly due to Drywell sprays in service. Highest observed Primary Containment pressure was 13 psig.
7. Primary Containment radiation on RI-8103A-D is 5.0 Rem/hour, the highest observed to this point.
8. Field Monitoring Teams have been mobilized by the Shift Dose Assessor.
9. Iodine air samples have been completed and a Committed Dose Equivalent (CDE)

Thyroid Dose has been calculated and verified. Total CDE Thyroid Dose is expected to be 30 Rem.

9. Due to concerns for the exposure the Field Monitoring Teams may receive, EP-AA EP-AA-113-F-03, Thyroid Blocking Agent Authorization Forms, have been completed and reviewed/approved by the Radiation Protection Manager.

G. INITIATING CUE As the Shift Emergency Director, authorize the attached Thyroid Blocking Agent Authorization Form (EP-AA-113-F-03), in accordance with EP-AA-113. Document the basis for your decision. PLOR215C Rev003 Page 4

H. PERFORMANCE CHECKLIST II STEP NO STEP ACT STANDARD 1 Obtain a copy of EP-AA-113, "Personnel P The examinee obtains the current Protective Actions". revision of EP-AA-113, "Personnel Protective Actions". 2 Use Section 4.4 of the procedure for KI P The examinee references section 4.4 of assessment. EP-AA-113. 

                                               **** NOTE: ****

IF the Operator requests to review the KI calculation, inform the Operator that the EP-MA- EP-MA 110-100-F-02 form is not currently available, but it has been verified and is accurate. 3 Analyze given conditions and determine P Examinee determines that a release IS in that a release IS in progress progress 

    *4     Recognize that the conditions for issuing     P     Examinee determines the conditions for KI are not currently met.                           Step 4.4.1.1.A are NOT met due to:
  • Condition 1: there is not a loss or potential loss of the Fuel Clad Barrier.
  • Condition 2: the projected iodine thyroid exposure will be < 50 Rem CDE.

(Examinee may discuss the following, but this is NOT critical because no on-site workers are specified.) The conditions for Step 4.4.1.1.B are NOT met since this applies to onsite workers, and:

  • Condition 1: there is not a loss or potential loss of the Fuel Clad Barrier.
  • Condition 2: the projected iodine thyroid exposure will be < 50 Rem CDE.

5 Determine that Thyroid Blocking Agent P Recognize and report that KI should not (KI) should not be issued. be issued. (Cue: Acknowledge report.) PLOR215C Rev003 Page 50f6

STEP NO STEP ACT STANDARD 

 *6    Deny authorizing the issuance of Thyroid    P                                    EP-AA-113-The examinee does not sign EP-AA-113 Blocking Agent.                                    F-03, "Thyroid Blocking Agent Authorization Form."

(Cue: Acknowledge denial.) 7 As an evaluator, ensure that you have P Positive Control Established. positive control of all exam material provided to the examinees (Task Conditions/Prerequisites AND procedures. Under "ACT" P - must perform S - must simulate TERMINATING CUE: When the examinee has determined the conditions for issuing KI are not met and EP-AA-113-EP-AA-113 F-03 "Thyroid Blocking Agent Authorization Form" is returned without authorization, the evaluator may terminate the exercise. PLOR215C Rev003 Page 6 of6

TASK CONDITIONS/PREREQUISITES

1. Unit 2 experienced a LOCA transient that resulted in a Site Area Emergency declaration.
2. A small steam leak continues to exist in the Turbine Building due to failure of both Inboard and Outboard MSIVs in the B line to close.
3. Reactor power is 2.34 E-5% and dropping.
4. RPV level is -120 inches and steady. Lowest RPV level during the transient was -160 inches.
5. RPV pressure is SOO psig and dropping slowly.
6. Primary Containment pressure on PR-250S is S psig and lowering slowly due to Drywell sprays in service. Highest observed Primary Containment pressure was 13 psig.
7. Primary Containment radiation on RI-S103A-D is 5.0 Rem/hour, the highest observed to this point.

S. Field Monitoring Teams have been mobilized by the Shift Dose Assessor.

9. Iodine air samples have been completed and a Committed Dose Equivalent (CDE) Thyroid Dose has been calculated and verified.

Total CDE Thyroid Dose is expected to be 30 Rem.

9. Due to concerns for the exposure the Field Monitoring Teams may receive, EP- AA-113-F-03, Thyroid Blocking Agent Authorization Forms, have been completed and reviewed/approved by the Radiation Protection Manager.

INITIATING CUE As the Shift Emergency Director, authorize the attached Thyroid Blocking Agent Authorization Form (EP-AA-113-F-03), in accordance with EP EP-AA-113. Document the basis for your decision.

EP-AA-113-F-03 Revision C Page 1 of2 THYROID BLOCKING AGENT AUTHORIZATION NAME: FM Team Member #1 Employee ID Number: 123456 NAME: FM Team Member #2 Employee ID Number: 234567 NAME: FM Team Member #3 Employee ID Number: 345678 NAME: FM Team Member #4 Employee ID Number: 456789 NAME: FM Team Member #5 Employee ID Number: 567891 NAME: FM Team Member #6 Employee ID Number: 678912 NAME: Employee ID Number: NAME: Employee ID Number: NAME: Employee ID Number: NAME: Employee ID Number: The above named personnel are hereby authorized to take Potassium Iodide (KI) for the purpose of protection against the inhalation/ingestion of radioactive 1-131. The dosage shall be one (1) 130 mg tablet per day for 10 consecutive days. CJVJdiation Protection :Manaeer current cfate/time

  • Radiation Protection Manager (Reviewed) Date I Time
  • Acknowledges review and evaluation for need to use KI and that emergency worker(s) have been briefed on the potential health risks associated with KI. (see back of this form for briefing details)
  1. Statio" Emergency Director (Authorization) Date I Time
  2. The Shift Manager (Shift Emergency Director) may approve prior to transferring Command and Control to the Station Emergency Director.

KI Issuance Verification

    • Radiation Protection Manager (Confirmation of KI Issuance) Date
    • Confirm that individuals listed on this authorization form have been issued a supply of KI and instructed to take appropriate dosage.

Document Retention SRRS 10 58.100

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Document Retention SRRS 10 ID - 58.100

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET 

                 ~      JPM                D      QUALIFICATION MANUAL          OJT MODULE LICENSED OPERATOR TRAINING LICENSED OPERATOR REQUALIFICATION                               02 M. J. Kelly EAL CLASSIFICATION WITH STATE AND LOCAL NOTIFICATIONS (MA3, wind from 300 degrees, airborne release not in progress)

APPROVALS: Signature {Title Date Signature {Title Date APPROVED FOR USE: Signature { 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: Sig nature/Date II PLOR233C Rev002 Page 1 of 7

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Senior Reactor Operator TASK-JPM DESIGNATOR: 2007540502 I PLOR-233C KIA: 2.4.41 SRO: 4.6 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" . .IPMs IPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be peliormed 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.

PLOR233C Rev002 Page 2 of7

B. TOOLS AND EQUIPMENT Prepared PMS Screen Print of Meteorlogical Data C. REFERENCES

1. EP-AA-112-100, Rev. 9, "Control Room Operations"
2. EP-AA-111, Rev. 15, "Emergency Classification and Protective Action Recommendations"
3. EP-MA-114-100, Rev. 13, "Mid-Atlantic State/Local Notifications"
4. EP-MA-114-100-F-01, Rev G, "State/Local Notification Form
5. EP-AA-112-100-F-01, Rev. K, "Shift Emergency Director Checklist"
6. EP-AA-1 007, Table PBAPS 3-1, Rev. 18, "Emergency Action Level (EAL) Matrix
7. EP-AA-114-F-01, Rev. D, "Release in Progress Determination Guidance" D. TASK STANDARD
1. Satisfactory task completion is indicated when EP-MA-114-100-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. 004, "ERO Performance - Performance Indicators Guidance".)

2. Estimated time to complete:
  • Event Classification: 15 minutes - Time Critical
  • State/Local Notification Form: 13 minutes - Time Critical 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 

     *** THIS IS A TIME CRITICAL JPM ***

At time = 0 seconds,

1. Unit 2 was at 100% power when all three Reactor Feed Pumps (RFP) tripped.
2. RPV water level rapidly dropped to below +1" but an automatic scram did not occur.

PLOR233C Rev002 Page 3 of 7

3. The Unit Reactor Operator depressed the Manual Scram Pushbuttons at -15" and a full reactor scram occurred; all rods inserted.
4. RPV water level dropped below -48", HPCI and RCIC started to return RPV water level to the normal band.
5. The MSIVs remained open, EHC controlled RPV pressure at 940 PSIG.
6. The cause of the event was determined to be a fire in the Feedwater Digital Control System panel on Turbine Building 165' elevation. The fire was extinguished in 17 minutes.
7. All radiation effluent monitors are at normal post-scram levels.

G. INITIATING CUE #1 (On separate sheet) As Emergency Director, determine if an EAL Classification is applicable, and if so, make the classification. Notify Examiner when declaration is made, if applicable. FOLLOW-UP CUE #2 (On separate sheet and is ONLY given to examinee if a classification has been determined) Complete EP-MA-114-100-F-01, State/Local Notification Form. Notify Examiner when State/Local Event Notification Form is completed. PLOR233C Rev002 Page 4 of 7

H. PERFORMANCE CHECKLIST ~ STEP ACT STANDARD NO I 

                                                 *** NOTE ***

IF this JPM is being performed in an area with other candidates such as Tabletop in a classroom, remind the candidates to NOT make any announcements out loud. 

                                                 *** 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 there was an                     P   Automatic RPS scram failure with a unsuccessful automatic scram and a                  successful manual scram.

successful manual scram. 

    *3     Determine that the fire did not affect a        P   Review of HA6 and HU6 concludes it is safety system required for safe shutdown.           not applicable to this event.
    *4     Determine that threshold MA3 in the             P   Threshold MA3 in the Failure of Reactor Failure of Reactor Protection System                Protection System Matrix is the correct Matrix is the correct classification.               classification due to RPS setpoint being exceeded (<1" RPV level) and an automatic scram did not reduce reactor power to subcritical.
    *5     Announce the event classification to the        S   ALERT is announced.

facility staff. 

                                                 *** NOTE ****

Record the time using the clock above the Full Core Display. Time = Determine if the elapsed time since the initiating cue exceeds 15 minutes. 

                                                  *** NOTE ***

Inform the examinee that the Public Address Announcement and the ERO Notification required by EP-AA-112-100-F-01, Shift Emergency Director Checklist, are NOT required for this JPM. 

                                                  *** NOTE ***

Cue #2: Complete the State/Local Event Notification Form EP-MA-114-100-F-01 The following steps are associated with completion of EP-MA-114-100-F-01, "State/Local Event Notification Form." 6 Complete Utility Message Number P Enter "1" for Utility Message Number 

    *7     Check the call status.                          P   "This is a drill" line is checked in Block #1.
    *8     Check the affected station.                    ~each Bottom" is checked in Block #2.

PLOR233C Rev002 Page 50f7

STEP STEP ACT STANDARD NO 

 *9   Check the event classification.            P  "ALERT" 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 hour 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 AND          P  EAL# "MA3" 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.

Prepared stickers with brief non-technical description may be used. 

*14   Check the non-routine radiological         P  "Airborne" non-routine radiological release status.                               release is NOT in progress is checked in Block #5A. EP-AA-114-F-01, "Release in Progress Determination Guidance" may be referenced.
*15   Enter the wind direction "degrees from."   P  "300" is entered as the wind direction degrees from in Block #6a.

(Cue: Wind direction is from 300 degrees.) 

*16   Enter the wind speed.                      P  Wind speed is entered as "10" miles per hour in Block #6b.

(Cue: Wind speed is 10 mph.) 

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

Recommendation. 

*18   Check 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. PLOR233C Rev002 Page 6 of 7

STEP STEP ACT STANDARD NO 

                                             *** 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 declaration exceeds 13 minutes. 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-114-100-F-01, "State/Local Event Notification Form" has been completed, the evaluator will terminate the exercise. PLOR233C Rev002

TASK CONDITIONS/PREREQUISITES 

           *** THIS IS A TIME CRITICAL JPM ***

At time = 0 seconds,

1. Unit 2 was at 100% power when all three Reactor Feed Pumps (RFP) tripped.
2. RPV water level rapidly dropped below +1" but an automatic scram did not occur.
3. The Unit Reactor Operator depressed the Manual Scram Pushbuttons at -15" and a full reactor scram occurred; all rods inserted.
4. RPV water level dropped below -48", HPCI and RCIC started to return RPV water level to the normal band.
5. The MSIVs remained open, EHC controlled RPV pressure at 940 PSIG.
6. The cause of the event was determined to be a fire in the Feedwater Digital Control System panel on Turbine Building 165' elevation. The fire was extinguished in 17 minutes.
7. All radiation effluent monitors are at normal post-post scram levels.

INITIATING CUE As the Emergency Director determine if an EAL Classification is applicable, and if so, make the classification. Notify Examiner when declaration is made, if applicable.

TASK CONDITIONS/PREREQUISITES 

            *** THIS IS A TIME CRITICAL JPM ***

At time = 0 seconds,

1. Unit 2 was at 100% power when all three Reactor Feed Pumps (RFP) tripped.
2. RPV water level rapidly dropped below +1" but an automatic scram did not occur.
3. The Unit Reactor Operator depressed the Manual Scram Push buttons at -15" and a full reactor scram occurred; all rods inserted.
4. RPV water level dropped below -48", HPCI and RCIC started to return RPV water level to the normal band.
5. The MSIVs remained open, EHC controlled RPV pressure at 940 PSIG.
6. The cause of the event was determined to be a fire in the Feedwater Digital Control System panel on Turbine Building 165' elevation. The fire was extinguished in 17 minutes.
7. All radiation effluent monitors are at normal post-post scram levels.

CUE #2 Complete EP-MA-114-100-F-01, Statei Local Notification Form. Notify Examiner when Statei Local Event Notification Form is completed.

Exel EP-MA-114-100-F-01 Revision G Nuclear Page 1 of 3 STATE/LOCAL EVENT NOTIFICATION FORM UTILITY MESSAGE NO. __ __1__1__ EMERGENCY DIRECTOR APPROVAL: APPROVAL:_ ______________ __ _ PERFORM INITIAL ROLL CALL PRIOR TO TRANSMITTING - Refer to Page 3 of Form

1. CALL STATUS is: 2. This is _ _ _ _ _ _ _ _ _ _ __ _

[Xl This is a DRILL. for [ ] LIMERICK / [Xl PEACH BOTTOM I [ ] TMI [ ] This is an ACTUAL EVENT. My phone number is The current [Communicator will provide his/her NAME, PHONE NUM TIME (in 24-hour clock) when notification is read.] 3.a EMERGENCY CLASSIFICATION b. AFFECTED UNIT{S) is/are: [ ] UNUSUAL EVENT [ ] ONE [X] TWO [ ] THREE [X] ALERT [ ] SITE AREA EMERGENCY c. DECLARED AT: [ ] GENERAL EMERGENCY TIME: _ _ _, _, [ ] RECOVERY DATE: / [ 1TERMINATION

4. a. EMERGENCY ACTION LEVEL (EAL) NO. is:

(Anything similar to the below wordin . . Wording does NOT have to be exact.) k Th~ reactor control rods failed to automatically shutdown the reactor when required. Current plant condition 00 NOT threaten public safety. radfol~lical release in-progress RNE radiological release in-progress LIQUID radiological release in-progress

d. Radiological release TERMINATED
6. METEOROLOGY is:
a. WIND DIRECTION is FROM: _--"3=O-,,,-O

_--"3=O-,,,-O_ _ _ (degrees)

b. WIND SPEED is: ~_---",10=-_ _ _ (miles per hour)

ANSWER KEY - DO NOT HAND OUT TO CANDIDATES Document Retention SRRS-ID-SB.100

EP-MA-114-100-F-01 Revision G Page 2 of 3 STATE/LOCAL EVENT NOTIFICATION FORM

7. UTILITY PROTECTIVE ACTION RECOMMENDATION: (a or b) - No action should be taken until government officials have been notified: by State:

[Xl a. NOT APPLICABLE (Unusual Event, Alert, Site Area Emergency, Tennination or Recovery only) (Complete the following for Shelter or Evacuation for a General Emergency only for the applicable station): [ ] b. The PROTECTIVE ACTION RECOMMENDATION (PAR) from the utility is: 

              ] SHELTER 360 DEGREES FROM 0 MILES (SITE BOUNDARY) TO _ _                            __  _

AND SHELTER THE FOLLOWING SECTORS FROM _ _ MILES TO _ _ []N []E [ ] S [ ] NNE [ lESE 

                                                    ] ESE                    [ ] SSW

[[ 1 

                       ] NE                      [ 1 SE                      [[ 1] SW

[[ 1 

                       ] ENE                     [ 1] SSE                     [ 1 WSW AND The utility recommends that government officials notify the                        to take potassium iodide (KI) for those sectors where shelter is recommended and                      ainder of the EPZ to monitor EAS Messages.

[ ] EVACUATE 360 DEGREES FROM 0 MILES (S (SIT, S MILES AND EVACUATE THE FOLLOWING SECTOR MILES: [[ 1 ] N [ 1] [X] [Xl W [[ 1 ] NNE [ 1] SSW [X] WNW [[ 1 ] NE [ 1] SW [Xl [X] NW [ ] ENE [ ] WSW [ 1 NNW AND The utility recommends officials notify the general public to take potassium potaSSium iodide (KI) for those sectors n is recommended and advise remainder of the EPZ to monitor EAS M [ ] SHELTER 360 (SITE BOUNDARY) TO _ _ MILES AND government officials notify the general public to take potassium potaSSium iodide where shelter is recommended and advise remainder of the EPZ to monitor 360 DEGREES FROM 0 MILES (SITE BOUNDARY) TO _ _ MILES lity recommends that government officials notify the general public to take potassium iodide those areas where evacuation is recommended and advise remainder of the EPZ to EASM [ ] This is an ACTUAL EVENT. PERFORM FINAL ROLL CALL UPON COMPLETION - Refer to Page 3 of Form

  • ASK if there are any questions regarding message or repeat backs needed
  • READ "This concludes the notification message"
  • FAX completed copies of all form pages to the Control Room, TSC and EOF, as applicable.
  • INFORM the Shift Manager (Shift Emergency Director), TSC Director or EOF Director, as applicable, when notification is completed to required contacts.

ANSWER KEY - DO NOT HAND OUT TO CANDIDATES Document Retention SRRS-ID-SB.100

EP-MA-114-100-F-01 Revision G Page 3 of 3 STATE/LOCAL EVENT NOTIFICATION FORM "15 Minute Notifications" "15 Minute Notifications" PEACH BOTTOM (CAN 833) LIMERICK (CAN 841) 

   "Notification Line": Dial "S33" for conference call. Stay on the line until ~Igencies come on                                        Initial Roll Call                           Final Roll Call "3 Digit Extensions". Make these calls from 3-digit lines.       (Time Contacted: 24-hour clock)                           (..J)
   "Commercial # From PBAPS": Make these calls from a 4-digit line. Dial "9-1-Area Code-Number"                                                     Pennsylvania EMA "Commercial # From PBABS 3-digit lines": Dial "7-1-9-1-Area                  Ext. 116 or 9-1-800-424-736 Code-Number" 9-1-717-651-2001 Initial Roll Call                                 Final Roll Call (Time Contacted: 24-hour clock)                           tv)                         Montgomery Ext. 117 or 9-1-6 Pennsylvania EMA                     D                                 Chest Ext 216 or 9-1-800-424-7362/

9-1-717-651-2001 Maryland EMA D Ext. 205 or 9-1-410-517-3600 York County D inute Notifications" Ext. 219 or 9-1-717-854-5571 Harford County D n Line": Dial "44" for all-call. If necessary, it extension #'s to notify individual agencies Ext. 214 or 9-1-410-638-3400 / ial # From TMI: Dial "9" and the # 9-1-410-638-4900 Commercial # From EOF: Dial "9-1-717" and the # Cecil County D Toll-Free SO~ # From TMI or EOF: Dial the #'s exactly as they appear below Ext. 234 or 9-1-410-398-2222/ Initial Roll Call Final Roll Call 9-1-410-392-2010 (Time Contacted: 24-hour clock) (..J) Lancaster County Pennsylvania EMA Ext. 315 or 9-1-800-424-7362 or Ext. 217 or 9-1-800-808-5 9-651-2001 9-1-717 -664-1 Cumberland County D Chester Co 319 or 9-238-9676, 9-243-4121 or 9-532-8878 1~ Lebanon County pleted Ext. 321 or 9-272-2025 / -7621 I -2054 Lancaster County D Ext. 318 or 9-664-1190 /-1200 York County D Ext. 317 or 9-854-5571, 9-840-2955 or ept. of the Environment 9-1-800-427-8347 F"m",rl"ll",nf'\/ ext. 292 or 235 Dauphin County D 9-1-866-633-4686 Ext. 320 or 9-911 or 9-558-6900 (time: 24-hour clock) Initial Roll Call Completed [ ] PA State Police, York Barracks Ext. 284 or 9-1-717-428-1011 FOLLOW*UP NOTIFICATIONS * (TMI) Contacted at: (time: 24-hour clock) [ ] York Haven Power Station 9-266-3654 or 9-818-3962 ... NOT required within 15 minutes of Classification Contacted at: (time: 24-hour clock) ANSWER KEY - DO NOT HAND OUT TO CANDIDATES Document Retention SRRS-ID - 58.100

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET JPM D QUALIFICATION MANUAL OJT MODULE PLOR-331CA LICENSED OPERATOR REQUALIFICATION 001 jav IN IN..IECT 

                 ..IECT SBLC (ALTERNATE PATH - LOW SBLC DISCHARGE PRESSURE)

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.l. EMPLOYEE ID NO. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: Signature/Date I II PLOR331CA Rev001 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: 2008060501/ PLOR-331CA KIA: 295037EA 1.04 URO: 4.5 SRO: 4.5 TASK DESCRIPTION: Perform Standby Liquid System Initiation During A Plant Event 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" ....IPMs, IPMs, 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.

PLOR331CA Rev001

B. TOOLS AND EQUIPMENT None C. REFERENCES RRC 11.1-2, Rev. 1, Standby Liquid System Initiation During a Plant Event D. TASK STANDARD

1. Satisfactory task completion is indicated when Standby Liquid Control is injecting into the RPV at adequate discharge pressure using the 'B' SBLC Pump.
2. Estimated time to complete: 12 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, inject SBLC into the RPV using the 'A' SBLC Pump using RRC 11.1-2, Standby Liquid System Initiation during a Plant Event. I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASK CONDITIONS/PREREQUISITES

1. An attempt has been made to scram the reactor.
2. An Electric ATWS has resulted and SBLC injection is required.
3. Reactor Pressure is 920 psig.
4. Reactor Level is in the normal band with feedwater in automatic control.

G. INITIATING CUE The Control Room Supervisor directs you, the Unit Reactor Operator, to inject Standby Liquid Control using the 'A' SBLC Pump in accordance with RRC 11.1-2, Standby Liquid System Initiation During a Plant Event. PLOR331CA Rev001 Page 3 of 5

H. PERFORMANCE CHECKLIST II II STEP NO STEP ACT STANDARD 1 Obtain a copy of procedure RRC 11.1-2. P A copy of procedure RRC 11.1-2 is obtained. 

     *2    Verify CLOSED the AO-39 AND AO-40,             P     Final State: AO-39 and A0-40 CLOSED, "Recirc Sample Inboard and Outboard                  as indicated by AO-39 AND AO-40 RED Isolation" valves.                                   lights are OFF and GREEN lights are ON on Panel 20C005A.

(Cue: Initially, cue candidate that AO-39 AND AO-40 RED Ijghts are ON and GREEN lights are OFF. After candidate addresses manipulating control switch to CLOSE the valves, then cue RED lights OFF and GREEN lights ON) 

     *3    Start the 'A' SBLC Pump.                       P     The SBLC switch is placed in the "START SYS An position on Panel 20C005A.

(Cue: Acknowledge switch movement.) 4 Verify that the RWCU system isolates. P Verify green lights ON and red lights OFF (Cue: Valves checked have the green for the following valves on Panel lights ON and the red lights off.) 20C004A: MO-2-12-15, RWCU Inboard Isolation MO-2-12-18, RWCU Outboard Isolation MO-2-12-68, RWCU Outlet valve I 

                                                **** NOTE: ****

The Alternate Path portion of this JPM begins with the next step. 

     *5    Verify that SBLC is injecting.                 P     Recognize that SBLC Pump discharge pressure on PI-2-11-065 is lower than (Cue: Pump Red Light is on, Discharge                reactor pressure and therefore SBLC is pressure 400 psig, tank level steady.)               NOT injecting.

PLOR331CA Rev001 Page 4 of 5

STEP NO STEP ACT STANDARD 

                                              *** NOTE ***

Candidate may immediately move to inject with the 'B' SBlC Pump OR may notify the CRS of the failure to inject. If the candidate chooses to notify the CRS and wait for direction, then repeat initial cue to "Inject Standby Liquid Control in accordance with RRC 11.1-2 'Standby Liquid System Initiation During a Plant Event' ". 

  *6    Start the 'B' SBlC Pump.                       P   The SBlC switch is placed in the "START SYS B" position on Panel 20C005A.

(Cue: Acknowledge switch operation.) 7 Verify that SBlC is injecting. P Verify that SBlC Discharge pressure is now greater than reactor pressure. (Cue when checked: Pump Red Light is i on, Discharge pressure 1050 psig, tank level is lowering.) 8 Inform Control Room Supervisor of task P Task completion reported. completion. (CUE!: Control Room Supervisor acknow-acknow ledges report.) 9 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 SBlC is injecting at greater than reactor pressure, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR331CA Rev001

TASK CONDITIONS/PREREQUISITES

1. An attempt has been made to scram the reactor.
2. An Electric ATWS has resulted and SBLC injection is required.
3. Reactor Pressure is 920 psig.
4. Reactor Level is in the normal band with feedwater in automatic control.

INITIATING CUE The Control Room Supervisor directs you, the Unit Reactor Operator, to inject Standby Liquid Control using the 'A' SBLC Pump in accordance with RRC 11.1-2, Standby Liquid System Initiation During a Plant Event.

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET II Peach Bottom II Limerick Common 

              ~      JPM              D      QUALIFICATION MANUAL          OJT MODULE LICENSED OPERATOR TRAINING                                   PLOR-332CA LICENSED OPERATOR REQUALIFICATION                            002 M. J. Kelly                                                  jav MANUALLY INITIATE RCIC (ALTERNATE PATH - RCIC FAILS TO ISOLATE)

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 1.0. NO. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: SignaturelDate PLOR332CA Rev002 Page 1

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2170410401 / PLOR-332CA K/A: 217000A4.03 URO: 3.4 SRO: 3.3 TASK DESCRIPTION: Take Actions For RCIC Steam Line Hi Flow 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.

PLOR332CA Rev002 Page 2 of9

B. TOOLS AND EQUIPMENT

1. None C. REFERENCES
1. RRC 13.1-2 Rev. 3, "RCIC System Operation During A Plant Event"
2. ARC 222 0-1, Rev. 5, "RCIC Steam Line Hi Flow"
3. GP-S.G, Rev.4, "PCIS Isolation - Groups V and V-B" D. TASK STANDARD
1. Satisfactory task completion is indicated when RCIC is manually isolated following failure of the system to automatically isolate on high steam supply line flow.
2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to manually initiate the RCIC system and inject into the Reactor vessel at a flow rate of approximately 600 gpm 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. Reactor Scram has occurred on low level due to a loss of all Feedwater.
2. Reactor level is -25" and dropping slowly.

G. INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to initiate the RCIC System using the RCIC Manual Initiation pushbutton and inject to the Reactor vessel at approximately 600 gpm using RRC 13.1-2 "RCIC System Operation During a Plant Event." PLOR332CA Rev002 Page 3 of 9

H. PERFORMANCE CHECKLIST I STEP NO t)ll:::jJ ACT I STANDARD 1 Obtain a copy of procedure RRC 13.1-2. P A copy of procedure RRC 13.1-2 is obtained. Section A, "Vessel Injection using Manual Initiation Push-button", is I referenced. 

    *2    Arm the RCIC Manual Initiation               P    RCIC Manual Initiation pushbutton collar is pushbutton, 13A-S80.                              rotated clockwise to the ARMED position
                                                          *at
                                                          *at panel 20COO4C.

(Cue: Acknowledge pushbutton collar operation; annunciator A-2 on alarm panel 222 is alarming.) 

    *3    Depress the RCIC Manual Initiation           P    RCIC Manual Initiation pushbutton is
        **pushbutton, pushbutton, 13A-S80.                              momentarily DEPRESSED at panel 20COO4C.

(Cue: Acknowledge Manual Initiation pushbutton operation; annunciator 222 C- C 5 "RCIC Barometric Condenser Vacuum Pump Running" is alarming.) 4 Acknowledge the "RCIC BAROMETRIC P The annunciator "ACKNOWLEDGE" CONDENSER VACUUM PUMP I pushbutton is depressed. RUNNING" annunciator. (Cue: Annunciator 222 C-5 is lit solid.) 5 Verify MO-2-13-131, RCIC Turbine Supply P MO-2-13-131 red light is verified ON at valve, opens. panel 20COO4C. (Cue: MO-131 red light is on, green light is off.) 6 ,Verify MO-2-13-021, RCIC to Feed Line P MO-2-13-021 red light is verified ON at valve, opens. panel 20COO4C. (Cue: MO-021 red light is on, green light is off.) 7 Verify MO-2-13-132, RCIC Cooling Water P MO-2-13-132 red light is verified ON at valve, opens. panel 20COO4C. (Cue: MO-132 red is off.) ~ PLOR332CA Rev002 Page 4 of9

1\ STEP I I 1\ NO STEP ACT STANDARD 10 Verif~ AO-2-13-034 and AO-2-13-035, P AO-2-13-034 and AO-2-13-035 green RCIC Drain Isol to Mn Cndr valves, close. lights verified ON at pane120C004C . 

         *(Cue: AO-034 and AO-035 green lights are on, red lights are off.)

11 Verify 20P046, Vacuum Pump, starts. P 20P046 red light verified ON at panel 20C004C. (Cue: 20P046 red light is on, green light is out. Alarm 222 C-5 lit.) 12 Verify RCIC system flowrate is 600 gpm. P *RCIC Flow is verified to be 600 gpm on pane120C004C. (Cue: FI-2-13-091 indicates 600 gpm. RCIC Flow Controller output meter 

         ,indicates 80%.)

13 Place the RCIC Manual Initiation P RCIC Manual Initiation pushbutton collar is pushbutton, 13A-S80, collar in the *rotated counter-clockwise to the 

                                                                              *rotated DISARMED position.                                                  DISARMED position at panel 20C004C.

(Cue: Acknowledge pushbutton collar I operation.) 14 Acknowledge the "RCIC STEAM LINE HI P The annunciator "ACKNOWLEDGE" FLOW" annunciator. pushbutton is depressed. (Cue: Annunciator 222 0-1 is lit solid.) 

                                                "''''' NOTE: "'''''

The Alternate Path portion of this JPM begins with the next step. step . PLOR332CA Rev002 Page 50f9

II STEP I. i I NO . STEP ACT STANDARD 15 Usin~~ ARC 222 0-1 determine that the P Using ARC 222 0-1 VERIFY that the RCIC system should have automatically following valves should have automatically isolated. closed, but did not: MO-2-13-015, (Cue: RCIC system is in operation and injecting into the reactor vessel at 600 MO-2-13-016, gpm.) MO-2-13-039, MO-2-13-041, AO-2-13-137, AO-2-13-138, M0-4487, MO-2-13-027. Verification of an actual high steam flow condition can also be accomplished by monitoring RCIC steam line leak detection instruments TE-4936A-D, 4937A-D, 4938A-D,4939A-D. Examinee may perform steps 16 through 30 in any order. 

   *16        TRIP RCIC turbine by depressing the         P    Depress the RCIC TRIP pushbutton on
              'TRIP" pushbutton.                               PaneI20C004C.

(Cue: The RCIC TRIP pushbutton is depressed.) 17 Verify closed MO-4487, "Trip Throttle P M0-4487 green light is verified ON at Valve". panel 20C004C. 

           **(Cue:

(Cue: M0-4487 green light is on, red light i is off.) 18 I Verify closed MO-2-13-027, "Min Flow". P MO-2-13-027 green light is verified ON at 20C004C. Cue: MO-2**13-027 green light is on red PLOR332CA Rev002 Page 6 of 9

I STEP NO STEP ACT STANDARD 19 Place control switch for MO-2-13-131, P Control switch for MO-2-13-131 is placed "Supply", to CLOSE. in the CLOSE position on Panel 20C004C. (Note: This step is NOT critical, and will only be performed if system is shutdown (Cue: Acknowledge control switch per the SO or RRC procedure - RCIC 

      .i operation.)

Isolation ARC and GP-B.G do NOT i manipulate this valve) 20 Verify closed MO-2-13-131, "Supply". P MO-2-13-131 green light is verified ON at pane120C004C. (Note: This step is NOT critical, and will only be performed if (Cue: MO-2-13-131 green light is on, red light is off.) system is shutdown per the SO or RRC 

                                                      . procedure - RCIC Isolation ARC and GP  GP-
                                                      *B.G
                                                      *B.G do NOT manipulate this valve)
  *21    Place control switch for MO-2-13-015,     P    Control switch for MO-2-13-015 is placed "Steam Isolation", to CLOSE.                   in the CLOSE position on Pane120C004C.

(Cue: Acknowledge control switch operation.) 22 Verify closed MO-2-13-015, "Steam P MO-2-13-015 green light is verified ON at Isolation". pane120C004C. (Cue: MO-2-13-015 green light is on, red light is off.) 

  *23    Place control switch for MO-2-13-016,     P    Control switch for MO-2-13-016 is placed "Steam Isolation", to CLOSE.                   in the CLOSE position on Pane120C004C.

(Cue: Acknowledge control switch operation.) 24 Verify closed MO-2-13-016, "Steam P MO-2-13-016 green light is verified ON at Isolation". pane120C004C. (Cue: MO-2-13-016 green light is on, red light is off.) 25 Verify closed MO-2-13-039, "Torus P MO-2-13-039 green light is verified ON at Suction". pane120C004C. (Cue: MO-2-13-039 green light is on, red light is off.) PLOR332CA Rev002 Page 7 9

~ STEP NO STEP ACT STANDARD 26 Verify closed MO-2-13-041, "Torus P MO-2-13-041 green light is verified ON at Suction". pane120C004C. (Cue: MO-2-13-041 green light is on, red light is off.) 

  *27    Place control switch for MO-2-13-137,     P  Control switch for MO-2-13-137 is placed "Isol", to CLOSE.                            in the CLOSE position on Pane120C004C.

(Cue: Acknowledge control switch i operation.) 28 Verify closed MO-2-13-137, "lsol". P MO-2-13-137 green light is verified ON at i pane120C004C. (Cue: MO-2-13-137 green light is on, red light is off.) 

  *29    Place control switch for MO-2-13-138,     P  Control switch for MO-2-13-138 is placed "lsol", to CLOSE.                            in the CLOSE position on Panel 20C004C.

(Cue: Acknowledge control switch operation.) 30 Verify closed MO-2-13-138, "lsol". P MO-2-13-138 green light is verified ON at panel 20C004C. (Cue: MO-2-13-138 green light is on, red 

       ! light is off.)

31 Inform Control Room Supervisor of task P Task completion reported. completion. (CUE~: Control Room Supervisor acknowledges report.) 32 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 PLOR332CA Rev002 Page

I. TERMINATING CUE When RCIC is manually isolated, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR332CA Rev002 Page 9 of 9

TASK CONDITIONS/PREREQUISITES

1. Reactor Scram has occurred on low level due to a loss of all Feedwater.
2. Reactor level is -25" and dropping slowly.

INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator" to initiate the RCIC System using the RCIC Manual Initiation pushbutton and inject to the Reactor vessel at approximately 600 gpm using RRC 13.1-2 "RCIC System Operation During a Plant Event".

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET 

                 ~      JPM               D      QUALIFICATION MANUAL                 OJT MODULE
                                                                         ~~~~------------~I Licensed Operator Training                                           PLOR-083C Licensed Operator Requalification                                    009 M. J. Kelly                                                          Mda Reopen The Main Steam Isolation Vallves After a GP I Isolation APPROVALS:

Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date II APPROVED FOR USE: EFFECTIVE DATE: _ _ ,-----_.,----- NAME: ISSUE DATE: Last First M.1. SOC. SEC. 1\10. COMPLETION DATE: COMMENTS: Training Review for Completeness: PIMS CODE: PIMS ENTRY: Signature/Date PLOR083C Rev009 Page 1 of 7

EXELON NUCLEAR PEACH BOnOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM 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. 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 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.

PLOR083C Rev009 Page 2 of 7

B. TOOLS AND EQUIPMENT None C. REFERENCES Procedure T-221-2, Rev. 8, "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 E. 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. PLOR083C Rev009 Page 3 of 7

H. PERFORMANCE CHECKLIST H STEP NO STEP ACT STANDARD 1 Obtain a copy of procedure T-221-2. P 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 (Cue: Acknowledge control switch              20COO3-01.

operation.) 3 Verify AO-2-02-086A "A" Outboard MSIV P AO-2-02-086A red light is verified ON at is open. panel 20COO3-01. (Cue: AO-2-02-086A red light is on, green light is off.) 

    *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 (Cue: Acknowledge control switch              20COO3-01.

operation.) 5 Verify AO-2-02-0868 "8" Outboard MSIV P AO-2-02-0868 red light is verified ON at is open. panel 20COO3-01. (Cue: AO-2-02-0868 red light is on, green light is Off.) 

    *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 (Cue: Acknowledge control switch              20COO3-01.

operation.) 7 Verify AO-2-02-086C "C" Outboard MSIV P AO-2-02-086C red light is verified ON at is open. paneI20COO3-01. (Cue: AO-2-02-086C red light is on, green light is off.) 

    *8  Open AO-2-02-086D "0" Outboard MSIV.       P  AO-2-02-086D control switch is placed in the "AUTO/OPEN" position at panel (Cue: Acknowledge control switch              20COO3-01.

operation.) PLOR083C Rev009 Page 4 of 7

STEP NO STEP ACT STANDARD 9 Verify AO-2-02-086D "0" Outboard MSIV P AO-2-02-086D red light is verified ON at is open. paneI20C003-01. (Cue: AO-2-02-086D red light is on, green light IS off.) 

   *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 paneI20C003-03.

(Cue: Acknowledge control switch operation.) i 11 Verify MO-2-02-077, Outboard Main P MO-2-02-077 red light is verified ON at Steam Drain valve open. paneI20C003-03. (Cue: MO-77 red light is on, green light is off.) 

   *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.

(Cue: Acknowledge control switch I operation.) 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. (Cue: MO-74 red light is on, green light is off.) 14 Verify closed MO-2-02-079, Orifice Bypass P MO-2-02-079 green light is verified ON at to Main Cndr valve. paneI20C003-03. (Cue: MO-79 green light is on, red light is off.) 

   *15   Open MO-2-02-078, Downstream Drain           P  MO-2-02-078 control switch is valve.                                          momentarily placed in the "OPEN" position at paneI20C003-03.

(Cue: MO-78 red light is on, green light is off.) Ii PLOR083C Rev009 Page 5 of 7

STEP NO STEP ACT STANDARD 16 Verify MO-2-02-078 Downstream Drain P MO-2-02-078 red light is verified ON at valvH is open. panel 20C003-03. (Cue: MO-78 red light is on, green light is off.) 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 pressure on PI-2-06-090A(B)(C) and 20C008A. 

         "Steam Line" pressure on PR-2865 on panel 20C008A.

(Cue: PI-2-06-090A(B)(C) indicates 540 psig and "Main Steam Pressure A" and "Main Steam Pressure B" indicate 485 psig and rising slowly.) 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, (Cue: PI-2-06-090A{B){C) is 400 psig and and "Steam Line" PR-2865 at panel Main Steam Pressure is 300 psig.) 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 (Cue: Acknowledge control switch                20C003-01.

operation. ) 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. (Cue: AO-2-02-080A red light is on, green light is off.) 

   *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 (Cue: Acknowledge control switch                20C003-01.

operation.) 22 Verify AO-2-02-080B "B" Inboard MSIV is P AO-2-02-080B red light is verified ON at open. panel 20C003-01 . (Cue: AO-2-02-080B red light is on, green light is off.) II PLOR083C Rev009 Page 6 of 7

IS~~P STEP ACT STANDARD 

    *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 (Cue: Acknowledge control switch               20COO3-01.

operation.) 24 Verify AO-2-02-080C "C" Inboard MSIV is P AO-2-02-080C red light is verified ON at open. paneI20COO3-01. (Cue: AO-2-02-080C red light is on, green light is off.) 

    *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 (Cue: Acknowledge control switch               20COO3-01.

operation.) 26 Verify AO-2-02-080D "0" Inboard MSIV is P AO-2-02-080D red light is verified ON at open. paneI20COO3-01. (Cue: AO-2-02-080D red light is on, green light is off.) 27 Inform Control Room Supervisor of task P Task completion reported. completion. acknow (Cue: Control Room Supervisor acknow-ledges report.) 28 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 I. TERMINATING CUE When the MSIVs have been reopened, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR083C Rev009 Page 7 of 7

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 T-221
        -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 Gener;ation Group OJTrrPE MATERIAL COVERSHEET Bottom 

                 ~      ....IPM IPM            D      QUALIFICATION MANUAL                OJT MODULE
                                                                              ~~~~----------~I Licensed Operator Requalification                                    PLOR-343CA Licensed Operator Requali'fication J. A. Verbillis Manually Initiate HPCI (Alternate Path - Suction Valves Fail to Auto Swap on CST Low Level)

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 ID#: COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: Signature/Date II PLOR343CA RevOOO

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-..IPM DESIGNATOR: 2060250101 / PLOR-343CA KIA: 206000A2.09 URO: 3.5 SRO: 3.7 TASK DESCRIPTION: Manually Initiate HPCI (Alternate Path - Suction Valves Fail to Auto Swap on CST Low Lev.!2ll 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" ....IPMs IPMs 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" ..IPMs, 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.

PLOR343CA RevOOO Page 2 7

B. TOOLS AND EQUIPMENT None C. REFERENCES

1. RRC 23.1-2, Rev. 5, "HPCI System Operation During A Plant Event"
2. Alarm Response Card 221 C-3, Rev. 4, Condensate Storage Tank Level Low-Low
3. Procedure SO 23.7.8-2, Rev. 7, "Transfer of HPCI Pump Suction from CST to Torus" 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 manually initiate the HPCI system and inject to the Reactor vessel at a flow rate of 5000 gpm 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. RPV Level is -25 inches and lowering slowly.
2. RCIC is isolated.

G. INITIATING CUE The Control Room Supervisor directs you to initiate the HPCI system using HPCI Manual Component Operation and inject to the Reactor vessel at 5000 gpm using RRC 23.1-2 "HPCI System Operation During A Plant Event". PLOR343CA RevOOO Page 3 of 7

H. PERFORMANCE CHECKLIST ~ STEP NO STEP ACT STANDARD 1 Obtain copy of RRC 23.1-2 "HPCI System P References Section A "HPCI Injection Operation During A Plant Event". Using Manual Initiation Push-button". 

   *2        Simultaneously start the Auxiliary Oil          P   Auxiliary oil pump control switch is placed Pump, 20P026 and open MO-2-23-014                   in the START position while
         ,**"Supply" "Supply" valve.                                     simultaneously placing MO-2-23-014 "Supply" control switch momentarily in the (Cue: Acknowledge control switch                    "OPEN" position at panel 20C004B.

operation.) 3 Verify the Auxiliary Oil Pump started. P Verify the Auxiliary Oil pump red light is ON at panel 20C004B or annunciator 222 (Cue: Auxiliary Oil pump red light is on D-5 is alarming at pane120C204C. green light is off and annunciator 222 D-5 is alarming, "HPCI AUXILIARY OIL PUMP RUNNING", Turbine Stop and Control valve red lights are on.) 4 Verify MO-2-23-014, "Supply" valve is P MO-2-23-14 red light verified ON, HPCI open. discharge pressure (PI-2-23-109) and HPCI speed (SPI-4505) rising at panel (Cue: MO-14 red light is on, green light is 20C004B. 

           ! off, HPCI discharge pressure and speed
           **rise.)

rise.) 

   *5        Open MO-2-23-019, liTo Feed Line" valve.        P   MO-2-23-019 control switch is momentarily placed in the OPEN position (Cue: Acknowledge control switch                    at panel 20C004B.

operation.) 6 Verify MO-2-23-019, "To Feed Line" valve P MO-2-23-019 red light is verified ON and is open. flow (FI-2-23-1 08) rising at panel 20C004B. (CUE~: MO-19 red light is on, green light is off, HPCI flow rise.) 

                                                    *** NOTE ***

The following step is NOT critical because the Gland Seal system is NOT safety-related. 7 Start the HPCI Gland Seal Condenser P HPCI Gland Seal Condenser Vacuum Vacuum Pump, 20K002. Pump control switch is placed in the START position at panel 20C004B. (Cue: Vac pump red light is on, green light is off.) PLOR343CA RevOOO

STEP NO STEP ACT STANDARD 8 Verify pump flowrate of 5000 gpm. P A HPCI flowrate of approximately 5000 gpm is verified on FI-2-23-108 at panel (Cue: FI-2-23-108 indicates 5000 gpm.) 20C004B. 

                                                   *** 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 Alternate Path ! portion of the JPM. 9 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. (Cue: Report Annunciator 221 C-3 is alarming.) 10 Obtain a copy of Alarm Response Card P Candidate references ARC 221 C-3, 221 C-3. CONDENSATE STOR TANK LEVEL LOW- LOW. 11 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 (CUE~: CST level is indicating 5 feet.) candidate may also send an EO to verify devel on LI-2210.) 12 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.) 

         **(Cue:

(Cue: Acknowledge report.) 13 Obtain a copy of procedure SO 23.7.B-2 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. II PLOR343CA RevOOO Page 5 of 7

STEP NO STEP ACT STANDARD 

*14    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.

(Cue: Acknowledge control switch operation. ) 

*15    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 panel 20C004B.

(Cue: Acknowledge control switch operation. ) 16 Verify MO-2-23-057 and MO-2-23-058, 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 panel 20C004B. 

     ! (Cue: MO-57 and MO-58 red lights are on, green lights are off.)

17 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. pane120C004B. I (Cue: MO-17 green light is off, red light is on.) 

*18    Close MO-2-23-017, Cond Tank Suction            P  MO-2-23-017 control switch is valve.                                             momentarily placed in the CLOSE position then released at panel 20C004B.

(Cue: Acknowledge control switch operation. ) 19 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. (Cue: MO-17 green light is on, red light is off.) 20 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 (Cue: Acknowledge direction.) failed auto transfer. PLOR343CA RevOOO

STEP NO STEP ACT STANDARD 21 Inform Control Room Supervisor that P Task completion reported. HPCI was manually started and is injecting into the RPV. (Cue: Control Room Supervisor acknowledges report.) 22 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 HPCI suction has been transferred to the Torus, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR343CA RevOOO Page 7 of 7

TASK CONDITIONS/PREREQUISITES

1. Reactor Level is -25 inches.
2. RCIC is isolated.

INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to initiate the HPCI system using HPCI Manual Component Operation and inject to the Reactor vessel at 5000 gpm using RRC 23.1-2 "HPCI System Operation During A Plant Event".

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET 

                 ~      JPM                D      QUALIFICATION MANUA         OJT MODULE LICENSED OPERATOR TRAINING                                   PLOR-034C LICENSED OPERATOR REQUALIFICATION                            013 M. J. Kelly                                                  jav CAD SYSTEM NITROGEN ADDITION TO CONTAINMENT DURING NORMAL OPERATIONS 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 ID NO. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: Sig nature/Date II PLOR034C Rev013 Page 1 af6

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor OperatorlSenior Reactor Operator TASK-JPM DESIGNATOR: 22401301011 PLOR-034C KIA: 223001A4.10 URO: 3.2 SRO: 3.2 TASK DESCRIPTION: CAD System Nitrogen Addition To Containment During Normal Operations 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 IPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
b. When performing "In-Plant" ....IPMs, IPMs, 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.

PLOR034C Rev013 Page 2 of6

B. TOOLS AND EQUIPMENT None C. REFERENCES

1. SO 7C.1.B-2, Rev. 18, "CAD System Nitrogen Addition to Containment During Normal Operations" (R)
2. SO 7J.1.A-2, Rev. 5, "Drywell and Torus H2/02 Sampling System Startup and Normal Operations - CAC Mode"
2. SO 7 J.7.C-2, Rev. 4, "Placing Drywell and Torus H2/02 Sampling System in Standby Mode and Removing from Standby Mode" D. TASK STANDARD
1. Satisfactory task completion is indicated when Nitrogen has been added to containment with an N2 flow of 55-65 scfm.
2. Estimated time to complete: 14 minutes (A. 5) Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to perform a normal nitrogen addition to the Drywell from the CAD 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. All SO 7C.1.B-2, "CAD System Nitrogen Addition to Containment During Normal Operations" procedural prerequisites are met.
2. Primary Containment venting is NOT required.
3. CAD Tank level is 45 inches.
4. 'A' Analyzer is in service and 'B' is in standby in the "CAC MODE."

G. INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to add nitrogen to the Drywell using "A" loop of the CAD system at 60 scfm in order to lower drywell Oxygen concentration in accordance with SO 7C.1.B-2 "CAD System Nitrogen Addition to Containment During Normal Operations," including placing the 'B' CAC/CAD Analyzer in service in accordance with SO 7J.7.C-2 "Placing Drywell and Torus H2/02 Sampling System in Standby Mode and Removing from Standby Mode" PLOR034C Rev013 Page 30f6

H. PERFORMANCE CHECKLIST "STEP STEP ACT STANDARD NO 1 Obtain a copy of procedure SO 7C.1 .8-2. P A copy of procedure SO 7C.1.B-2 is obtained. The Examinee should identify step 4.5.1 as the step needing to be performed. 

   *2   Open SV-4948A Drywell Nitrogen Supply         P     SV-4948A control switch is placed in the valvE~.                                             OPEN position at panel 20C484A.

(Cue: Acknowledge control switch operation.) 3 Verify SV-4948A Drywell Nitrogen Supply P ISV-4948A red light is verified ON at panel valve is open. .20C484A. (Cue: SV-4948A red light is on and green light is off.) 

   *4    Open SV-4949A Drywell Nitrogen Supply        P     SV-4949A control switch is placed in the Valve.                                              OPEN position at panel 20C484A.

(Cue: Acknowledge control switch operation. ) 5 Verify SV-4949A Drywell Nitrogen Supply P SV-4949A red light is verified ON at panel Valve is open. 20C484A. (Cue: SV-4949A red light is on and green light is off.) 

   *6    Open CV-4947A using HCS-4947A to              P    HCS-4947A manual adjustment knob is obtain a flow rate of 60 scfm on FI-4947A.         rotated clockwise until 50 to 70 scfm is obtained on FI-494 7A at panel 20C484A.

(Cue: [CLOCKWISE HCS-4947A manual adjustment knob is rotated.] HCS-4947A indicates 55% controller output; FI-4947A indicates 60 scfm; FR-4947A indicates 62 scfrn. 

                                              *** NOTE ***

Steps 7 through 17 place the B CAC/CAD analyzer in service from the standby mode per SO 7J.7.C-2. Step 4.1 of that SO directs the operator to SO 7J.1.A-2 "Drywell and Torus H2/02 Sampling S'ystem Startup and Normal Operations - CAC Mode" if the analyzer requires reset - which could and does happen when analyzer is manipulated too slowly. IF the candidate transitions out of SO 7J.7.C-2, THEN they should use SO 7J.1.A-2 to do a normal startup of the analyzer in the CAC mode. IF the candidate uses S07J.1.B-2 "Drywell and Torus H2/02 Sampling System Startup and Normal Operations - CAD Mode," THEN the analyzer will still be started up but not in the desired mode. Per discussion with the NRC exam team, this should NOT be graded as a failure, but the error should be critiqued. PLOR034C Rev013 Page 4 of6

STEP STEP ACT STANDARD NO 7 Obtain copy of SO 7J.7.C-2 P Procedure obtained 

 *8. On XIC-80411 (8), Press "6" Key to enter    P  6 key depressed monitor mode (Cue: Appropriate Display)
 *9. At XIC-80411 (8), Enter Access Code 82      P  "82" entered on keypad, ENTER key and press ENTER Key                            depressed (Cue: Appropriate Display)
*10. At XIC-80411 (8), Press "3" Key to select   P  3 key depressed CHANGE array (Cue: Appropriate Display)
*11. At XIC-80411 (8), Press "5" Key to select   P  5 key depressed MISCELLANEOUS array (Cue: Appropriate Display)
*12. At XIC-80411 (8), Press "4" Key to select   P  4 key depressed USER SYS array (Cue: Appropriate Display)
*13. At XIC-80411 (8), when ENTER ELEMENT        P  WHEN ENTER ELEMENT appears, THEN prompt appears, press 0 key                    o key depressed (Cue: ENTER ELEMENT appears -

appropriate display follows key entry) 

*14. At XIC-80411 (8), Press "ENTER" Key         P    NTER key depressed (Cue: A~~ro~riate Display)
*15. At XIC-80411 (8), Press "3" Key to change   P  3 key depressed false to true (Cue: "3" key depressed, display changes from FALSE to TRUE)
 *16  At XiC-80411 (8), Press "ENTER" Key 3       P  ENTER key depressed 3 times times (Cue: Appropriate Display)
 *17  At XIC-80411 (8), Press "ESC" Key 2 times   P  ESC key depressed 2 times (Cue: Appropriate Display) 18  Verify proper operation of analyzer by      D  Use of Routine Inspection SO is performing SO 7J.8.A-2.                        acknowledged (CUE!: Inform candidate that Routine Inspection is not required for purposes of JPM) 19   Inform the Control Room Supervisor of      P  Task completion reported.

task completion. (Cue: Control Room Supervisor acknow acknow-ledges report.) 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. PLOR034C Rev013 Pa9e 50f6

Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When nitrogen is being added to the Orywell at a flow rate of 60 scfm, and the second H2/02 monitor is in service, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR034C Rev013 Page 6 of6

TASK CONDITIONS/PREREQUISITES

1. All SO 7C.1.B-2, "CAD System Nitrogen Addition to Containment During Normal Operations" procedural prerequisites are met.
2. Primary Containment venting is NOT required.
3. CAD Tank level is 45 inches.
4. 'A' Analyzer is in service and 'B' is in standby in the "CAC MODE."

INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to add nitrogen to the Drywell using "A" loop of the CAD system at 60 scfm in order to lower drywell Oxygen concentration in accordance with SO 7C.1.B-2, "CAD System Nitrogen Addition to Containment During Normal Operations," including placing the 'B' CAC/CAD Analyzer in service in accordance with SO 7J.7.C-2 "Placing Drywell and Torus H2/02 Sampling System in Standby Mode and Removing from Standby Mode"

EXELON NUCLEAR Nuclear Generation Group OJT/TPE MATERIAL COVERSHEET 

              ~       JPM               D      QUALIFICATION MANUAL            OJT MODULE LICENSED OPERATOR TRAINING                                       PLOR-322CA LICENSED OPERATOR REQUALIFICATION                                001 J. R. Felice                                                     jav DIESEL GENERATOR LOAD TEST (ALTERNATE PATH - LOAD CONTROL DIFFICULTY)

APPROVALS: Signature I Title Date APPROVED FOR USE: Signature I Title Date EFFECTIVE DATE: _ _ _------' NAME: ISSUE DATE: Last First M.1. EMPLOYEE ID 10 NO. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: Signature/Date PLOR322CA Rev001

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2640020101/ PLOR-322CA KIA: 264000A4.04 URO: 3.7 SRO: 3.7 TASK DESCRIPTION: Diesel Generator Load Test (Alternate Path - Load Control Difficulty) 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.

PLOR322CA Rev001

B. TOOLS AND EQUIPMENT Synchronizing Switch Removable Handle C. REFERENCES Procedure SO 52A.1.B, Rev. 42, "Diesel GenE~rator Operations" (R) D. TASK STANDARD

1. Satisfactory task completion is indicated when the E-43 breaker has been opened OR the E-4 Diesel Generator tripped by the! examinee (due to E-4 Diesel Generator load control difficulty).
2. Estimated time to complete: 23 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, synchronize the! E-4 Diesel to the E-43 bus and pick up 2600 KW and 1000 KVAR for testing purposes 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 E-4 Diesel Generator has been "SLOW" started and is running in accordance with Section 4.1 of SO 52A.1.B, "Diesel Generator Operations."
2. The E-4 Diesel Generator is running at rated frequency and voltage.
3. The E-43 Bus is being supplied by 2SUE.
4. The ESW system is supplying Diesel Generator cooling water.

G. INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to synchronize the E-4 Diesel Generator to the E-43 Bus and pick up 2600 KWand 1000 KVAR in accordance with Section 4.2 of SO 52A.1.B, "Diesel Generator Operations." PLOR322CA Rev001

H. PERFORMANCE CHECKLIST II STEP STEP ACT STANDARD NO 1 Obtain a copy of procedure SO 52A.1.B. P A copy of procedure SO 52A.1.B is obtained. 2 Verify E-4 DIG is running at rated P E-4 DIG frequency is verified at 58.8 to frequency and voltage. 61.2 Hz on E-4 DIG Freq. meter. E-4 DIG voltage is verified at 4.16 to 4.4 KV on E-4 DIG Volt meter. (Cue: E-4 DIG frequency is 60 HZ and voltage is 4280 volts.) 

      *3    Insert Sync scope key in E-43 Breaker        P  E-43 Breaker Sync Switch (3-125-1807) is Sync Switch and turn ON.                        placed in the "ON" position at panel 00C026A.

(Cue: Both Sync Scopes rotating, incoming and running lights "ON" at Bottom Dead Center and "OFF" at Top Dead Center.) 4 VerifY E-4 DIG speed control. P E-4 DIG frequency is raised to 60.5 Hz then lowered to 59.5 Hz on E-4 DIG FREQ (Cue: "GOVERNORII control switch meter using the "GOVERNOR" control raises, lowers frequency 0.5 Hz switch (165-DG12) then returned to the abovelbelow the initial value, then returns initial value at panel 00C026D. to in1tial value.) 5 VerifY E-4 DIG voltage control. P E-4 DIG voltage is raised and lowered 50 volts abovelbelow initial value on E-4 DIG (Cue: "AUTO VOLT REG" raises then volts meter using the "AUTO VOLT REG" lowers voltage 50 volts abovelbelow initial control switch (90-DG14) then returned to value, then returns to initial value.) the initial value at panel 00C026D. 6 Check both synchronizing lights for proper P Both sync lights are verified "ON" at operation. Bottom Dead Center and "OFF" at Top Dead Center at panels 00C026A or I (Cue: Both lights "ON" when sync scope 00C026C. 

!~ottom Dead Center" and both lights
.*          "OFF" when sync scope at Top Dead Center".)

PLOR322CA Rev001 Page 4 of 9

STEP STEP ACT I STANDARD NO 

   *7     Adjust E-4 DIG engine speed using            P    Sync scope is verified rotating 1 revolution "GOVERNOR" control switch until sync             15 to 1 seconds in "FAST" direction at scope is rotating 1 revolution I 5 to 10          panels 00C026A OR 00C026C.

seconds in "FAST" direction. (Cue': Acknowledge control switch 

       **(Cue':

operation. Synchroscope is rotating 1 revo~ution I 5 to 10 seconds in the fast direction.) 

   *8     Adjust E-4 diesel generator voltage until    P    Incoming voltmeter about 50 volts but less "INCOMING" voltmeter is slightly higher          than 100 volts above bus voltage at panel than "RUNNING' voltmeter.                         00C026C.

(Cue: Acknowledge control switch operation. Incoming is slightly higher (50 volts) than running.) 9 Verify sync scope rotating 1 revolution I 5 P Sync scope is verified rotating 1 revolution to 10 seconds in "FAST" direction. 15 to 10 seconds in "FAST" direction at Panels 00C026A OR 00C026C. (Cue: Sync scope rotating 1 revolution I 5 to 10 seconds in "FAST".) 

  *10     Close the E-43 breaker when the sync         P    When the sync scope is within 13 degrees scope is within 13 degrees of "Top Dead           of "Top Dead Center", the E-43 breaker
        **Center".

Center". control switch is taken to the "CLOSED" position and released at panel 00C026D. (Cue: Acknowledge [CLOCKWISE] breaker control switch operation.) 11 Verify the E-43 breaker is closed. P E-43 breaker red light lit, sync scope stopped at 12 o'clock, and sync lights (Cue: E-43 breaker red light on, both sync "OFF" verified at panel 00C026C and scopes stopped at 12 o'clock and sync 00C026D. lights "OFF".) 

  *12     Immediately load the E-4 diesel to           P    E-4 DIG KW load is promptly raised by 200**300 KW by placing "Governor" control         momentarily placing the "GOVERNOR" switch to "RAISE"                                 control switch (165-DG12) to "RAISE" at panel 00C026D. No reverse power trip of (CUE~: [CLOCKWISE, "GOVERNOR"                     the E-43 breaker occurs.

control switch is taken to "RAISE"]. 13 Verify E-4 DIG load is 200-300 KW. P E-4 DIG load is verified to be 150 - 350 KW on the E-4 DIG KW meter at panel (Cue: E-4 DIG load is 250 KW.) 00C026D. [ PLOR322CA Rev001 Page 50f9

STEP STEP ACT STANDARD NO 14 Immediately load the E-4 Diesel Generator P E-4 DIG KVAR load is promptly raised by to 100 KVAR raised by placing the AUTO momentarily placing the AUTO VOLT VOLT REG control switch in "RAISE" REG control switch (90-DG14) in "RAISE" at panel OOC026D. (Cue: [CLOCKWISE, AUTO VOLT REG control switch is taken to "RAISE"]. 15 Verify E-4 DIG load is 100 KVAR. P E-4 DIG load is verified to be 50-150 KVAR on the E-4 DIG KVAR meter at panel OOC026D. (Cue: E-4 DIG load is 100 KVAR.) 16 Place the E-43 "BKR SYNC" switch to P E-43 "BKR SYNC" switch taken to "OFF" "OFF". at Panel 00C026D. (Cue: Acknowledge COUNTERCLOCKWISE control switch Ioperation.) operation. ) 17 Verify the E-43 "BKR SYNC" in "OFF". P "BKR SYNC" verified in "OFF" via INCOMING and RUNNING voltmeters dropping to zero. (Cue: INCOMING AND RUNNING voltmeters drop to zero.) 18 Check generator output voltage for all 3 P Generator output voltage is checked by phases. rotating the VOLT SEL switch through positions "1-2", "2-3", "3-1" on panel (Cue: Acknowledge VOLT SEL switch operation, reading is 4280 Volts on each OOC026D. phase) 19 Check generator amperage for all 3 P Generator amperage is checked by phases. rotating the AMP SEL switch through positions "1", "2", "3". (CUEt: Acknowledge AMP SEL switch operation, reading is >0 Amps on each phase) 

                                           *** N01"IE: ****

The Alternate Path portion of this JPM begins with the next step" 20 Pick up desired KW and KVAR loading on P E-4 DIG "Governor" control switch E-4 DIG. (165-DG12) and AUTO VOLT REG control switches are momentarily placed in Cue: [CLOCKWISE, "GOVERNOR" and "RAISE". AUTO VOLT REG control switches are momentarily placed in "RAISE".]. PLOR322CA Rev001

STEP STEP ACT STANDARD NO 21 VerifY' E-4 DIG load. P E-4 DIG load is verified to be 1500 KW and rising fast on the E-4 DIG KW meter (Cue: E-4 DIG load is 1500 KW and rising at panel 00C026D. fast.) 22 Attempt to reduce E-4 DIG loading rate to P E-4 DIG "GOVERNOR" control switch below 300 KW I minute. (165-DG12) taken to lower at panel 

      *Cue: [COUNTERCLOCKWISE,                            00C026D .
      ! "GOVERNOR"      control switch is taken to "LO\NER"].

23 Verify E-4 DIG load. P E-4 DIG load is verified to be 2500 KW and rising fast on the E-4 DIG KW meter (Cue: E-4 DIG load is 2500 KWand rising at panel 00C026D. fast.) 24 Attempt to reduce E-4 DIG loading rate to P E-4 DIG "GOVERNOR" control switch below 300 KW I minute. (165-DG12) taken to lower at panel Cue: [COUNTERCLOCKWISE, 00C026D. 

        "GOVERNOR" control switch is taken to "LOWER"].

25 Verify E-4 DIG load. P E-4 DIG load is verified to be approximately 3500 KW and stable on the (Cue: E-4 DIG load is approximately 3500 E-4 DIG KW meter at panel 00C026D. KW and stable.) Note SO 52A.1.B contains the following CAU,.ION: "CAUTION* Any operation over 3250 KW will require an engine shutdown, declaration of inoperability AND performance of an internal inspection." Anyone of the three actions in Step 26 will reduce the engine loading. 

 *26    Reduce E-4 DIG loading to below 3000            P Action taken to reduce load within 1 KW OR trip the E-43 breaker OR stop the           minute of load reaching and settling at E-4 DIG.                                          3400 kw. Acceptable action is Cue: ([COUNTERCLOCKWISE],                         described below.
        "GOVERNOR" control switch is taken to E-4 DIG "GOVERNOR" control switch "LOWER" OR E-43 breaker control switch (165-DG12) is promptly taken to lower placed in TRIP OR the E-4 DIG control switch placed in "STOP."                          until E-4 DIG load is below 3000 KW OR the E-43 breaker control switch is taken to the "TRIP" position and released OR the E-4 DIG control switch is taken to "STOP" and released at panel 00C026D.

PLOR322CA RevOO1 of

~ STEP ACT STANDARD NO 27 Verify action taken in the previous step. P E-4 DIG load is verified below 3000 KW and stable on the E-4 DIG KW meter at (Cue: E-4 DIG load is below 3000 KW panel 00C026D OR the E-43 breaker and stable OR E-43 breaker green light green light on, red light off, KW and KVAR on, red light off, KW and KVAR load load indicate zero at panel 00C026D. indicated zero.) I 

                                               *** NOTE ***

JPM Steps 28 through 35 do not apply if the E-43 breaker or E-4 DIG were tripped in the above step. 28 Reduce E-4 DIG loading to 1300 KW. P E-4 DIG "GOVERNOR" control switch (165-DG 12) is taken to lower at panel Cue: [COUNTERCLOCKWISE, 00C026D. E-4 DIG is run at 1300 KW for "GOVERNOR" control switch is taken to 5 minutes. 

          "LOWER"].

29 Verify E-4 DIG load. P E-4 DIG load is verified 1300 KW on the E-4 DIG KW meter at panel 00C026D. (Cue: E-4 DIG load is 1300 KWand stable - 5 minutes have elapsed) 30 Reduce E-4 DIG loading to 100 -150 KW. P E-4 DIG "GOVERNOR" control switch (165-DG12) is taken to lower at panel Cue: [COUNTERCLOCKWISE, 00C026D. 

          "GOVERNOR" control switch is taken to "LOWER"].

31 Verify E-4 DIG load. P E-4 DIG load is verified 50 - 200 KW on the E-4 DIG KW meter at panel 00C026D. (Cue: E-4 DIG load is 100 - 150 KW and stable.) 32 Reduce E-4 DIG load to 50 KVAR. P E-4 DIG KVAR load is LOWERED by momentarily placing the AUTO VOLT REG control switch (90-DG14) in (CUE!: [COUNTERCLOCKWISE, AUTO "LOWER" at panel OOC026D until E-4 VOLT REG control switch is taken to DIG load is 25 - 75 KVAR. 

          "LOWER"].

33 Verify E-4 DIG load at 50 KVAR. P E-4 DIG load is verified 25 - 75 KVAR on the E-4 DIG KVAR meter at panel (Cue: E-4 DIG load is 50 KVAR.) 00C026D 

    *34   Trip the E-43 breaker.                        P     The E-43 breaker control sWitch is taken to the 'TRIP" position and released at (CUE: Acknowledge                                   panel 00C026D.

COUNTERCLOCKWISE control switch Ii I operation.) PLOR322CA Rev001 Page 80f9

~ STEP ACT STANDARD NO 35 Verify the E-43 breaker is open. P Verify E-43 breaker green light on, red light off, KWand KVAR load indicate zero (CUE: E-43 breaker green light on, red at panel OOC026D. light off, KW and KVAR load indicate zero.) 36 Shutdown the EDG by taking the Control P Control Switch placed in STOP. Switch to STOP. (CUE: Control Switch placed in STOP) 36 Notify the Control Room SupelVisor that P Information provided to the Control Room the E-43 breaker is open, the E-4 D/G is SupelVisor. inoperable and that an internal inspection of the E-4 D/G is required. (CUE: Control Room SupelVisor acknowledges report.) 37 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 E-43 breaker is opened OR D/G tripped by the examinee, then the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR322CA Rev001

TASK CONDITIONS/PREREQUISITES

1. The E-4 Diesel Generator has been "SLOW" started and is running in accordance with Section 4.1 of SO 52A.1.B, "Diesel Generator Operations. "
2. The E-4 Diesel Generator is running at rated frequency and voltage.
3. The E-43 Bus is being supplied by 2SUE.
4. The ESW system is supplying Diesel Generator cooling water.

INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to synchronize the E-4 Diesel Generator to the E-43 Bus and pick up 2600 KW and 1000 KVAR in accordance with Section 4.2 of SO 52A.1I1B, "Diesel Generator Operations."

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET ach Bottom Comm 

                ~       JPM               o      QUALIFICATION MANUAL                 OJT MODULE LICENSED OPERATOR TRAINING                                             PLOR-270C LICENSED OPERATOR REQUALIFICATION                                      000 J. A. Verbillis                                                       jav ECW System Makeup to Tower using ESW System APPROVALS:

Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date I APPROVED FOR USE: Signature f 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 PLOR270C RElVOOO

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2770140401/ PLOR-270C KIA: 400000 A4.01 URO: 3.1 SRO: 3.0 TASK DESCRIPTION: ECW System Makeup to Tower using ESW System 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.

PLOR270C RevOOO Page 2 of 7

B. TOOLS AND EQUIPMENT None C. REFERENCES

1. AO 33.2 Rev 6 "Emergency Service Water System Manual Startup and Operations"
2. AO 48.1 Rev 5 "Emergency Cooling Water System Makeup to Tower Using the Emergency Service Water System"
3. SO 33.1.A Rev 2 "Emergency Service Water System Setup for Normal Standby Operation" .
4. SO 33.2.A Rev 4 "Emergency Service Water System Shutdown" D. TASK STANDARD
1. Satisfactory task completion is indicated when:

Emergency Cooling Tower level is at or about 18 Ft 3 In, and Emergency Service Water is returned to a standby lineup.

2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to makeup to the Emergency Cooling Tower with the Emergency Service Water 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. Emergency Cooling Water tower level is 17 ft.
2. No Emergency Diesel Generators are in service.
3. The ESW System is lined up for normal operation in accordance with SO 33.1.A, "Emergency Service Water System Setup for Normal Standby Operation".
4. Att 1 of AO 48.1 "ECW System Makeup to Tower Using the ESW System" is complete.

G. INITIATING CUE The Control Room Supervisor directs you to makeup to the Emergency Cooling Tower to a level of 18 ft 3 in, then restore to a normal lineup, using AO 48.1 "Emergency Cooling Water System Makeup to the Tower Using the Emergency Service Water System." PLOR270C RevOOO Page 3 of 7

H. PERFORMANCE CHECKLIST II STEP NO STEP ACT STANDARD 1 Obtain a copy of procedure AO 48.1. P A copy of procedure AO 48.1 is obtained. 2 Verif)' open MO-0501A(8,C) "ESW Inlet". P On Panel 00C123, at least ONE valve (MO-0501A, 8, or C) verified Open. (Cue: Valve(s) Red lights On, Green lights Off.) 3 Obtain a copy of AO 33.2 for starting the P A copy of AO 33.2 is obtained ESW pump 4 Direct Equipment Operator to verify "A" or P IF AO procedure is used for starting ESW "8" ESW Pump motor oil level at STAND pump, THEN this check is made STILL level (Cue: Report as EO that "An or "8" ESW Pump motor oil level at STAND STILL level 

   *5   Start "A" OR "8" ESW Pump.                  P    On Panels 00C0268/00C026C, (Cue: Acknowledge control switch               *A
                                                       *A or 8 ESW pump control switch operation. )                                    manipulated.

6 Verify "A" OR "8" ESW Pump operating P ESW pump parameters verified to be in as expected. expected range per SO 33.8.8. (Cue: Red Light On, Pump amps initially peg high then settle at about 26 amps, discharge pressure is 50 psig.) i 

   *7   Depress MO-0498, "Permit to Close"          P    On Panel 00C123, MO-0498 "Permit to pushbutton                                     . Close" pushbutton depressed.

(Cue: Acknowledge pushbutton operation) 

   *8   Close MO-0498, "ESW Disch to Pond".         P    On Panel OOC 123, MO-0498, "ESW Disch to Pond" is taken to Close (Cue: Acknowledge control switch operation) 9   Verify MO-0498 is closed.                   P    MO-0498 verified CLOSED.

(Cue: Red light ON, Green Light OFF.) PLOR270C RevOOO

STEP NO STEP ACT STANDARD 10 Verify the "AUTO" ESW Booster Pump P WHEN MO-0498 is closed, starts. THEN verify the following: 

                                                                          - The "AUTO" ESW Booster Pump starts.

(CUE!: Red light lit, motor current 30 amps, - Motor current 30 amps (25 to 35 amps) discharge pressure 50 psig, Alarm ARC-ARC as indicated on itA ESW Booster Pump" 212 A-1, ESW Booster Pump A or B Auto- Auto ammeter on Panel OOC 123 Start in Alarm.) - Discharge pressure 50 psig (40 to 65 psig) as indicated on PI-0550, "ESW Booster Purnp Disch Header" on Panel 00C123. 

                                                 "''NOTE''''

In the following step, ECT level as indicated on LI-0503 WILL NOT CHANGE, so this information must be CUED to the Candidate. 11 Monitor ECT reservoir level. P Observe level indicator LI-0503, "Clg Twr" on Panel 00C123. (Cue: ECT reservoir level is slowly rising.) 

      *(Cue: Inform candidate that ECT level is
      . now 18 feet, 3 inches.)                                        I*

I 

                                                "'' NOTE "''

In the following step, the sequence of shutdown of the ESW Booster pumps is not critical. If the Running ESW Booster Pump is taken to OFF first, the Standby pump may auto-start. 

 *12    Shutdown the ESW booster pump by                       P          "A" and "B" ESW Booster Pump control taking the "A" and "B" pump control                               switches taken to OF F.

switches in OFF. (Cue: Acknowledge switch operation.) 13 Verify "A" OR "B" ESW Booster Pump P ESW Booster pump parameters verified to shutdown as expected. be as expected for shutdown pump. (Cue: Red light OFF, Green light ON, Pump amps 0, discharge pressure is 0 psig.) 

 *14    Open MO-0498.                                          P          Control switch taken to OPEN.

(Cue: Acknowledge switch operation.) 15 Obtain a copy of SO 33.2.A for shutting P A copy of SO 33.2.A is obtained down the ESW pump PLOR270C RevOOO Page 5 of 7

STEP NO STEP ACT STANDARD 

*16   Shutdown the running ESW pump.           P  Running ESW Pump control switch taken to OFF.

(Cue: Acknowledge switch operation.) 17 Verify "A" OR liB" ESW Pump shutdown P ESW pump parameters verified to be as as expected. expected for shutdown pump. (Cue: Red light OFF, Green light ON, Pump amps 0, discharge pressure is 0 psig.) 18 Verify MO-0498 Open. P MO-0498 verified OPEN. (Cue: Red light ON, Green light OFF.) 

 *19  Place "A" ESW Booster Pump switch in     P  "A" ESW Booster Pump placed in AUTO.

AUTO position. (Cue: Acknowledge switch operation.) 

 *20  Place "B" ESW Booster Pump switch in     P  "B" ESW Booster Pump placed in AUTO AUTO STDBY position.                        STDBY.

(Cue: Acknowledge switch operation) 21 Direct Equipment Operator to return DG P EO directed to perform Att 2 of AO 48.1. Heat Exchanger outlet valves to normal lineup by completing Att 2 of AO 48.1. (Cue: Acknowledge direction to perform Att 2 - Report Att 2 complete.) 22 Direct Equipment Operator to drain ESW P EO directed to perform SO 48.4.A. Piping lAW SO 48.4.A (Cue: Inform candidate that this is not required for this JPM) 23 Inform Control Room Supervisor of task P Task completion reported. completion. (Cue: Control Room Supervisor acknowledges report.) 24 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 PLOR270C RevOOO

I. TERMINATING CUE When the lineup for making up to the Emergency Cooling Tower is secured, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR270C RevOOO Page 7 of7

TASK CONDITIONS/PREREQUISITES

1. Emergency Cooling Water tower level is 17 ft.
2. No Emergency Diesel Generators are in service.
3. The ESW System is lined up for normal operation in accordance with SO 33.1.A, "Emergency Service Water System Setup for Normal Standby Operation".
4. Att 1 of AO 48.1 "ECW System Makeup to Tower Using the ESW System" is complete.

INITIATING CUE The Control Room Supervisor directs you to makeup to the Emergency Cooling Tower to a level of 18 ft 3 in, then restore to a normal lineup, using AO 48.1 Emergency Cooling Water System Makeup to Tower Using the Emergency Service Water System.

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

                      ..IPM                    QUALIFICATION MANUAL
                   ------------~~------------------

D OJT MODULE PLOR-018C LICENSED OPERATOR REQUALIFICATION 013 J. R. Felice mda ANUALLY PLACE SBGT ON EQUIPMENT CELL EXHAUST 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.I. EMPLOYEE ID NO. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: SignaturelDate PLOR018C Rev013 7

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2610070101 I PLOR-018C KIA: 295017AA1.09 RO: 3.6 SRO: 3.8 TASK DESCRIPTION: Manually Place SBGT on Equipment Cell Exhaust 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.

PLOR018C Rev013 Page 2

B. TOOLS AND EQUIPMENT None C. REFERENCES

1. Procedure SO 9A.7.G Rev. 13, "SBGT Manual Startup on Equipment Cell Exhaust" (R)
2. ST-O-09A-500-2 Rev. 4, "SBGT Filter Train Operation Log" (A)

D. TASK STANDARD

1. Satisfactory task completion is indicated when SBGT operating on Equipment Cell Exhaust.
2. Estimated time to complete: 9 minutes (A.5) Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to place SBGT on Equipment Cell Exhaust 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. Standby Gas Treatment System lined up for automatic operation per SO 9A.1.A, "Standby Gas Treatment System Lineup for Automatic Operation"
2. Operator stationed at Reactor Building Vent Pane120C132.
3. Standby Gas Treatment Filter Train "A" has the least amount of run-hours.

G. INITIATING CUE The Control Room Supervisor directs you to place SBGT on Equipment Cell Exhaust using SO 9A.7.G,"Standby Gas Treatment System Manual Startup on Equipment Cell Exhaust". PLOR018C Rev013 Page 3 of 7

H. PERFORMANCE CHECKLIST Ii STEP STEP ACT STANDARD NO 1 Obtain a copy of procedure SO 9A.7.G. P A copy of procedure SO 9A.7.G is obtained. 2 Notify Health Physics that SBGT is to be P Health Physics notified that SBGT is to started on Unit 2 Equipment Cell be started on Unit 2 Equipment Cell Exhc:lust. Exhaust. (CUE~: Health Physics acknowledges notification. ) 

     *3  Open PO-20465, Exh To SBGT Equip           P  PO-20465 control switch placed in the Cell Damper.                                  OPEN position at panel 20C012.

(Cue: Acknowledge control switch operation.) 4 Verify PO-20465, Exh To SBGT Equip P PO-20465 red light verified ON at panel Cell Damper is open. 20C012. (Cue: PO-20465 red light is on, green light is off.) 

     *5  Open AO-20469-1, SBGT OW Rx Bldg           P  AO-20469-1 control switch placed in the Exh Damper.                                   OPEN position at pane120C012.

(Cue: Acknowledge control switch operation.) (Evaluator Note: This step is critical IF AO-20469-2 is NOT opened.) 6 Verify AO-20469-1, SBGT OW Rx Bldg P AO-20469-1 red light verified ON at panel Exh Damper is open. 20C012. (Cue: AO-20469-1 red light is on, green light is off.) 

     *7  Open AO-20469-2, SBGT OW Rx Bldg           P  AO-20469-2 control switch is placed in Exh Damper.                                   the OPEN position at panel 20C012.

(CUl3: Acknowledge control switch operation.) (Evaluator Note: This step is critical IF AO-20469-1 is NOT opened.) PLOR018C Rev013

STEP STEP ACT STANDARD NO B Verify AO-20469-2, SBGT DW Rx Bldg P AO-20469-2 red light verified ON at panel Exh Damper is open. 20C012. (CUH: AO-20469-2 red light is on, green light is off.) 

 *9   Open AO-00475-1, SBGT "A" Filter Inlet     P  AO-00475-1 control switch is placed in Damper.                                       the OPEN position at panel 20C012.

(CUH: Acknowledge control switch operation.) 10 Verify AO-00475-1, SBGT "A" Filter Inlet P AO-00475-1 red light verified ON at panel Damper is open. 20C012. Acknowledges annunciator 216 A-5 "SBGT Filters Not in Auto". (Cue: AO-0475-1 red light is on, green light is off.) 

*11   Open AO-00475-2, SBGT "A" Filter           P  AO-00475-2 control switch is placed in Outlet Damper.                                the OPEN position at panel 20C012.

(Cue: Acknowledge control switch operation.) 12 Verify AO-00475-2, SBGT "A" Filter P AO-00475-2 red light verified ON at panel Outlet Damper is open. 20C012. (CUE~: AO-00475-2 red light is on, green light is off.} 

*13   Start "A" SBGT Fan.                        P  "A" SBGT Fan control switch is placed in the RUN position at panel 20C012.

(Cue: Acknowledge control switch operation. ) 14 Verify the "An SBGT Fan Start. P SBGT Flow rises to approx. 6000 SCFM on FR-2000B, "A" SBGT Filter i!P rises to (Cue: Flow rises to approx. 6000 SCFM 1" H20 on DPI-20001 and "A" SBGT Fan on FR-2000B and "Aft SBGT Filter i!P red light verified ON at panel 20C012. rises to 1" H20 on DPI-20001 "A" SBGT Fan red light is on, green light is off.) 15 Wait 3 to 5 seconds after "A" SBGT fan P AO-20467 is closed more than 3 seconds starts to close AO-20467. after "A" SBGT fan is started. 

*16   Close AO-20467, Ventilation Exhaust        P  AO-20467 control switch is placed in the Equip Cell Damper.                            CLOSE position at pane120C012.

(Cue: Acknowledge control switch operation. ) PLOR018C Rev013

STEP STEP ACT STANDARD NO 17 Verify AO-20467, Ventilation Exhaust P AO-20467 green light verified ON at Equip Cell Damper is closed. pane120C012. (Cue: AO-20467 green light is on, red light is off.) 

   *18   Close AO-20468, Ventilation Exhaust          P  AO-20468 control switch is placed in the Equip Cell Damper.                              CLOSE position at panel 20C012.

(Cue: Acknowledge control switch operation.) 19 Verify AO-20468, Ventilation Exhaust P AO-20468 green light verified ON at Equip Cell Damper is closed. pane120C012. Acknowledges annunciator 216 L-1. (Cue: AO-20468 green light is on, red light is off.) 20 Direct Equipment Operator to verify P Equipment Operator directed to verify the Equipment Cell Exhaust Fans 2AV18 and Equipment Cell Exhaust Fans not running 2BV18 are not running and verify the and Fan control switches in "OFF". control switches for both of the Equipment Cell Exhaust Fans are in "OFF". (CUE~: Equipment Operator reports 2AV18 and 2BV18 are not running and both of the Equipment Cell Exhaust Fan control switches are in "OFF".) 21 Verify proper operation of the SBGT P The "A" SBGT Filter DP is verified to be system. in Expected Performance Region of Figure 1 of SO 9A.7.G and SBGT System (CUE~: SBGT Filter DP is in the Expected flow is verified to be between 2000 and Performance Region of SO 9A.7.G, 9000 SCFM on FR-20008. Figure 1.) 22 Verify Unit 2 Reactor Building differential P Reactor Building DPI-20003-01 indicates pressure between -.1 and -.4" H20 as between -.1 and -.4" H2O. indicated on DPI-20003-01. (CUE~: Reactor Building DP is between - 0.1 and -0.4" H2O.) 23 Verify Unit 2 Refuel Floor differential P Equipment Operator is directed to verify pressure between -.1 and -.4" H20 as Refuel Floor DPI-20003-02 indicates indicated on DPI-20003-02. between -.1 and -.4" H2O. (Cue: Refuel Floor DP is between -0.1 Il and -0.4" H2O.) PLOR018C Rev013 Page 6 of7

II S~~p STEP ACT STANDARD 24 log start time in the SBGT Filter Train P logs start time in ST-O-09A-500-2, Data Run log in accordance with ST-O-09A- 

                                          -O-09A            Sheet 1.

500-2. (CUE!: Start time is logged in ST-O-09A-ST-O-09A 500-2.) 25 Inform Control Room Supervisor of task P Task completion reported. completion. (Cue: Control Room Supervisor acknowledges report.) 26 As a n 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 Equipment Cell Exhaust is placed on Standby Gas Treatment, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR018C Rev013

TASK CONDITIONS/PREREQUISITES

1. Standby Gas Treatment System lined up for automatic operation per SO 9A.1.A, "Standby Gas Treatment System Lineup for Automatic Operation"
2. Operator stationed at Reactor Building Vent Panel 20C132.
3. Standby Gas Treatment Filter Train "A" has the least amount of run-hours.

INITIATING CUE The Control Room Supervisor directs you to place SBGT on Equipment Cell Exhaust using SO 9A.7.G, "Standby Gas Treatment System Manual Startup on Equipment Cell Exhaust".

EXELON NUCLEAR Nuclear Generation Group OJTrrPE MATERIAL COVERSHEET ach Bottom ih=d1/[Umerick II Common JPM D QUALIFICATION MANUAL D OJT MODULE PLOR-313PA LICENSED OPERATOR REQUALIFICATION 006 J.A. Verbillis jay CLOSING A STUCK OPEN MSIV -ALTERNATE PATH (UNIT 3) 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 ID NO. COMPLETION DATE: COMMENTS: Training Review for Completeness: LMS CODE: LMS ENTRY: Signature/Date PLOR313PA Rev006 Page 1 7

EXELON NUCLEAR PEACH BOnOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2390110401/ PLOR-313PA KIA: 239001A2.12 URO: 4.2 SRO: 4.3 TASK DESCRIPTION: Closing a Stuck Open MSIV - Alternate Path (Unit 3) 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 IPMs are designed to be performed in the simulator. If a "Control Room" ....IPM 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 JPM:s, 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.

PLOR313PA Rev006 Page 2 of 7

B. TOOLS AND EQUIPMENT

1. Insulated Fuse Pullers
2. Radio
3. AO 1A.2-3, Rev. 10 "Closing a Stuck Open Inboard or Outboard Main Steam Isolation Valve"
4. SO 16A.7.A-3 "Backup Instrument Nitrogen to ADS System Manual Actuation" C. REFERENCES
1. AO 1A.2-3, Rev. 10 "Closing a Stuck Open Inboard or Outboard Main Steam Isolation Valve"
2. SO 16A. 7.A-3 "Backup Instrument Nitrogen to ADS System Manual Actuation" D. TASK STANDARD
1. Satisfactory task completion is indicated when the Unit 3 Reactor Building 135' Elevation Instrument Air headers have been vented.
2. Estimated time to complete: 22 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to close the stuck open outboard MSIVs using AO 1A.2-3, "Closing a Stuck Open Inboard or Outboard Main Steam Isolation Valve". 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 has just been manually scrammed (Unit 3 Mode Switch in "Shutdown").
2. RPV level is -175 inches (Group 1 isolation signal is present).
3. All outboard MSIVs failed to isolate.
4. Proper operation of SGIG system has been verified in accordance with SO 168.8.A-3, "Backup Seismic Instrument Nitrogen System Routine Inspection".
5. Radiological conditions do NOT allow entry into the Outboard MSIV Room.

PLOR313PA Rev006 Page 3 of7

G. INITIATING CUE The Control Room Supervisor directs you to close the Unit 3 Outboard MSIVs in accordance with AO 1A.2-3, "Closing a Stuck Open Inboard or Outboard Main Steam Isolation Valve", beginning with step 4.1.3 and continuing with procedure until outboard MSIVs are closed. PLOR313PA Rev006 Page 4 of7

H. PERFORMANCE CHECKLIST II STEP STEP ACT STANDARD NO 1 Obtain a copy of procedure AO 1A.2-3 and P A copy of procedure AO 1A.2-3 and a set a set of insulated fuse pullers. of insulated fuse pullers are obtained. (Fuse pullers can be obtained from WCS or 4th RO work station, or other locations) 

                                                  ** NOTE **

Examinee should utilize sections 4.1 AND 4.4 of AO 1A.2-3. 2 Open panel 30C042 front panel doors. P Door handle turned, doors pulled outward to gain access to the outboard MSIV AC (Cue: Panel 30C042 doors are open.) and DC solenoid valve fuses at the front of panel 30C042 in the Cable Spreading Room. 

     *3   Pull the outboard MSIV AC solenoid valve        S       Fuse puller is attached to outboard MSIV fuse F4 (16A-F12B, 4th fuse from top) of                AC solenoid valve fuse F8 (16A-F12B) terminal strip BB.                                      fuse is pulled outward until fuse is free of fuse holder. (For NRC Exams, if asked, (Cue: Fuse is removed.)                                 cue that Concurrent Verification has been waived. For Station Exams, cue per
                                                                . Exelon guidance on Verification i Practices).

4 Direct the Unit Reactor Operator to S Unit Reactor Operator is contacted to monltor outboard MSIV position indication. monitor outboard MSIV position indication. (Cue~: Outboard MSIVs are open.) 

                                                **** NOTE: ****

The Alternate Path portion of this JPM begins with the next step. 

     *5   Pull the outboard MSIV DC solenoid valve        S I Fuse puller is attached to outboard MSIV 8th fuse from top) of fuse F8 (16A-F11 B, 8th                                 DC solenoid valve fuse F8 (16A-F11 B).

terminal strip BB i Fuse is pulled outward until fuse is free of fuse holder. (Cue: Fuse is removed.) 6 Direct the Unit Reactor Operator to S Unit Reactor Operator is contacted to monitor Main Steam line flow using FI FI-3 monitor Main Steam line flow on FI-3-06 FI-3 06-088A, B, C, 0 on panel 30COO8A. 088A, B, C, 0 at panel30COO8A. (Cue: Main Steam line FI-3-06-088A, B, 

         ,C, 0 are NOT reading downscale.

Position indication for all outboard MSIVs has been lost.) 

     *7                           8th fuse from top) of Install F8 (16A-F11B, 8th                       S       Fuse puller is attached to outboard MSIV terminal strip BB.                                      DC solenoid valve fuse F8 (16A-F11B).

Fuse is inserted until fuse is installed in (Cue: Fuse is installed.) fuse holder. PLOR313PA Rev006

STEP P STEP ACT STANDARD NO 8 Direc:t Unit Reactor Operator to unlatch S Unit Reactor Operator directed to unlatch and release test pushbutton for the and release test pushbutton. Outboard MSIV. (Cue: Pushbutton released - OR - Step 4.1.8 is complete) 9 Close panel 30C042 front panel doors. P Door closed and re-Iatched using handle. 

         *(Cue: Panel 30C042 doors are closed.)

10 Direct the Unit Reactor Operator to verify S Unit Reactor Operator is contacted to RWCU isolation, verify RWCU isolation. (Cue: RWCU is isolated - OR - Step 4.4.1 is complete) 11 Direct the Unit Reactor Operator to open S Unit Reactor Operator is contacted to Backup N2 to ADS valves SV-9130A AND verify Backup N2 to ADS valves SV-9130A B in accordance with SO 16A.7.A-3. AND B in accordance with SO 16A.7.A-3. (Cue: SV-9130A AND B are open in accordance with SO 16A.7.A-3. If asked to verify proper operation of SGIG system, then report that the SGIG system is operating properly in accordance with SO 16B.8.A OR - Steps 4.4.2 and 4.4.3 are complete) 

   *12      Close Instrument Air A Header Isolation       S  HV-3-36B-56981A handwheel turned valvE~s HV-3-36B-56981 A                         clockwise until the resistance of the valve (Cue: The valve handwheel has been               seat is felt (3B Recirc MG Set area).

turned clockwise until it will turn no further.} further.) 

   *13      Close Instrument Air B Header Isolation       S  HV-3-36B-56981 B handwheel turned valves HV-3-36B-56981 B                          clockwise until the resistance of the valve seat is felt (3B Recirc MG Set area).

(Cue: The valve handwheel has been turnE~d clockwise until it will turn no further.) 14 Verify open Instrument Air Supply to DT-DT S HV-3-36B-An attempt is made to turn HV-3-36B 569S Inlet Block valve HV-3-36B-54642. 54642 handwheel is turned slightly in the clockwise direction and then turned (Cue: The valve handwheel is turned counterclockwise to the original position slightly in the clockwise direction and then (3B Recirc MG Set area). turned counterclockwise to the original position. 15 Verify open Instrument Air Supply to DT-DT S HV-3-363 An attempt is made to turn HV-3-363-5696 inlet block valve HV-3-36B-54643. 54643 handwheel is turned slightly in the clockwise direction and then turned (CUE!: The valve handwheel is turned counterclockwise to the original position slightly in the clockwise direction and then (3B Recirc MG Set area). turned counterclockwise to the original II  ! position. PLOR313PA Rev006

STEP STEP ACT STANDARD NO 16 Notify the Control Room that venting is S Unit Reactor Operator is contacted and commencing and to perform more frequent notified of venting and Outboard MSIV monitoring of MSIV position. position monitoring. (Cue: Control Room acknowledges notification.) 

  *17    Simultaneously press and hold Drain Trap      S                                     HS                                                             Drain Trap 8ypass pushbuttons HS-3 8ypass switches HS-3-368-5695 AND                 368-5695 AND HS-3-368-5696 are HS-3,-368-5696.                                   simultaneously depressed and held (38 Recirc MG Set area).

(Cue: HS-3-368-5695 AND HS-3-368-HS-3-368 5696 are simultaneously depressed and held. You hear air flowing from both Drain i Traps. The sound of the air flowing throLigh the drain traps is diminishing.) 18 When it is reported that all Unit 3 Outboard S Drain Trap 8ypass pushbuttons HS-3 HS MSIVs are closed, then release both Drain 368-5695 AND HS-3-368-5696 are Trap Pushbuttons HS-3-368-5695 and released (38 Recirc MG Set area). HS-~~-368-5696. (Cue: You hear a report through your radio that all of the Unit 3 Outboard MSIVs are closed and both Drain Trap Pushbuttons HS-3-368-5695(6) may be released.) 19 Inform Control Room Supervisor of task S Task completion reported using telephone, completion. hand held radio or GAI-TRONICS page system. (Cue: Control Room Supervisor acknow-acknow ledges report. Outboard MSIVs are closed.) 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 the Unit 3 outboard MSIVs are closed, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR313PA Rev006 Page 7

TASK CONDITIONS/PREREQUISITES

1. Unit 3 has just been manually scrammed (Unit 3 Mode Switch in "Shutdown").
2. RPV level is -175 inches (Group 1 isolation signal is present).
3. All outboard MSIVs failed to isolate.
4. Proper operation of SGIG system has been verified in accordance with SO 16B.8.A-3, "Backup Seismic Instrument Nitrogen System Routine Inspection".
5. Radiological conditions do NOT allow entry into the Outboard MSIV Room.

INITIATING CUE The Control Room Supervisor directs you to close the Unit 3 outboard MSIVs in accordance with AO 1A.2-3, "Closing a Stuck Open Inboard or Outboard Main Steam Isolation Valve", beginning with step 4.1.3 and continuing with procedure until outboard MSIVs are closed.

EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET on 

               ~ ....IPM IPM                      QUALIFICATION MANUAL D

I I OJT MODULE Licensed Operator Training PLOR-075P Licensed Operator Requalification .. 015 J. R. Felice . . .* jav jav SCRAM SOLENOID DE-ENERGIZATION - UNIT 2 (T-213-2) APPROVALS: Signature f Title Date Signature f Title Date Signature f Title Date APPROVED FOR USE: Signature f 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: Signature/Date PLOR075P Rev015 5

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2003730599/ PLOR-075P KIA: 295037EA 1.01 295037EA1.01 RO: 4.6 SRO: 4.6 TASK DESCRIPTION: Scram Solenoid De-energization - Unit 2 (T-213-2) 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" ,.I PM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
b. When performing "In-Plant" ....IPMs, IPMs, 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.

PLOR075P Rev015 Page 2 of 5

B. TOOLS AND EQUIPMENT

1. T -213-2, Rev 10 "Scram Solenoid Deenergization"
2. T-213-3, Rev 10 "Scram Solenoid Deenergization"
3. EOP Tool Box Key (obtain from Training Clerical Staff)
4. Screwdriver C. REFERENCES Procedure T-213-2, Rev. 10, "Scram Solenoid De-energization" (R)

D. TASK STANDARD

1. Satisfactory task completion is indicated when Unit 2 Control Rods 06-15 and 22-43 scram solenoid fuses are removed.
2. Estimated time to complete: 5 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to de-energize Unit 2 Control Rods 06-15 and 22-43 scram solenoids 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. An auto scram occurred on Unit 2 due to partial loss of Feedwater flow.
2. Control Rods 06-15 and 22-43 are stuck at position 48 with their blue scram lights NOT lit on the Full Core Display.
3. All "Control Rod Drive Scram Solenoid Group 1, 2, 3, 4" white lights are lit.
4. Use of procedure T-213-2, "Scram Solenoid Deenergization" has been directed by the TRIP procedures.
5. Procedure steps up to and including step 4.3 of procedure T-213-2 have been completed.
6. The Scram Discharge Volume (SDV) iB not isolated.

G. INITIATING CUE The Control Room Supervisor directs you, thE~ Equipment Operator, to de-energize Unit 2 Control Rods 06-15 and 22-43 scram solenoids in accordance with Step 4.4 of procedure T-213-2, "Scram Solenoid Deenergization". PLOR075P Rev015 Page 3 of 5

H. PERFORMANCE CHECKLIST II 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 Produces own copy of Tool Locker Key. WECS key box and its associated key then evaluator should provide the EOP Tool Locker key. Examinee may produce their copy of Tool Locker Key.) 

     *2     Open Emergency Operation Procedure           P    Tool Locker (located on Radwaste Tool Locker and obtain T -213 Tool Kit            Building EI. 165') is unlocked, opened and equipment.                                        T-213 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 screwdriver and a copy of the T -200 procedure which corresponds to the tool kit that has been chosen. Copies of T -213-2 and T -213-3 are available in the event the candidate selects the kit for the wrong unit. DO NOr allow equipment to be removed from the locker. Relock the locker before leaving the area. 

     *3     Open panel 2AC068 door.                       P   Panel fasteners unfastened, door pulled outward to gain access to Control Rod (CUEl: Panel2AC068 door is open.)                 06-15 and 22-43 fuses.
     *4     Pull the Channel A fuse for Control Rod       S   Control Rod 06-15 Channel A fuse is 06-15.                                            removed from the top left side of panel 2AC068 using fuse puller from T -213-2 (Cue: Fuse is removed.)                           Tool Kit.
     *5     Pull the Channel B fuse for Control Rod       S   Control Rod 06-15 Channel B fuse is 06-15.                                            removed from the top right side of panel 2AC068 using fuse puller from T -213-2 (Cue: Fuse is removed. Control Room               Tool Kit.

reports Control Rod 06-15 is inserting.) 6 Initial on Table 1 by Control Rod 06-15. P T-213-2, Table 1 is initialed under "FUSES REMOVED" column by Control Rod (Cue: Acknowledge initialing Table 1.) 06-15. PLOR075P Rev015 Page 4 of 5

a NO 

    *7 STEP Pull the Channel A fuse for Control Rod 22-43.

ACT S STANDARD Control Rod 22-43 Channel A fuse is removed from panel 2AC068 (15 Row) th using fuse puller from T-213-2 Tool Kit. (Cue: Fuse is removed.) 

    *8  Pull the Channel B fuse for Control Rod   S     Control Rod 22-43 Channel B fuse is th 22-43.                                          removed from panel 2AC068 (15 Row) using fuse puller from T -213-2 Tool Kit.

(Cue: Fuse is removed. Control Room reports Control Rod 22-43 is inserting.) 9 Initial on Table 1 by Control Rod 22-43. P T-213-2, Table 1 is initialed under "FUSES REMOVED" column by Control Rod (Cue: Acknowledge initialing Table 1.) 22-43. I 10 Inform Control Room of task completion. S T ask completion reported using telephone, hand held radio or GAI-TRONICS page (Cue: Control Room acknowledges report. system. Control Rod 06-15 and 22-43 blue scram lights are lit.) 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 Control Rods 06-15 and 22-43 scram solenoid fuses have been pulled, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR075P Rev015 Page 5 of 5

TASK CONDITIONS/PREREQUISITES

1. An auto scram occurred on Unit 2 due to partial loss of Feedwater flow.
2. Control Rods 06-15 and 22-43 are stuck at position 48 with their blue scram lights NOT lit on the Full Core Display.
3. All "Control Rod Drive Scram Solenoid Group 1, 2, 3, 4" white lights are lit.
4. Use of procedure T -213-2, "Scram Solenoid Deenergization" has been directed by the TRIP procedures.
5. Procedure steps up to and including step 4.3 of procedure T-213-2 have been completed.
6. The Scram Discharge Volume (SDV) is not isolated.

INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to de-energize Unit 2 Control Rods 06-15 and 22-43 scram solenoids in accordance with Step 4.4 of procedure T-213-2, "Scram Solenoid Deenergization".

EXELON NUCLEAR Nuclear Generation Group O..IT/TPE O ..IT/TPE MATERIAL COVERSHEET l!:=dJ/[i)meriCk II Common JPM I ' ......'" ,"-" 

                                                                 ** ",ATION MANUAL      D               O"IT MODULE PLOR-271P LICENSED OPERATOR REQUALIFICATION                                                       000 J. A. Verbillis                                                    TYIP~I~~* * *. *rl;1 rl;1 jav BACKUP INSTRUMENT NITROGEN TO ADS SYSTEM STARTUP AND OPERATION (Unit 3)

APPROVALS: Signature I Title Date Signature I Title Date APPROVED FOR USE: I Title 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 I PLOR271 P RevOOO Page 1 of6

EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2180060101/ PLOR-2'?1P KIA: 218000A2.03 URO: 3.4 SRO: 3.6 TASK DESCRIPTION: Backup Instrument Nitrogen to ADS System Startup and Operation (Unit 3) 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 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.

PLOR271 P RevOOO Page 2 of6

B. TOOLS AND EQUIPMENT

1. SO 16A.1.A-3 Rev. S, "Backup Instrument Nitrogen to ADS Startup and Operation"
2. COL 16A.1.A-3 Rev. 3, "Backup Instrument Nitrogen to ADS System" C. REFERENCES
1. SO 16A.1.A-3 Rev. S, "Backup Instrument Nitrogen to ADS Startup and Operation"
2. COL 16A.1.A-3 Rev. 3, "Backup Instrument Nitrogen to ADS System"
3. P&ID M-333 Sh 2 Rev OS7 Instrument Nitrogen D. TASK STANDARD
1. Satisfactory task completion is indicated when backup Instrument Nitrogen to ADS has been lined up locally.
2. Estimated time to complete: 23 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to line up Backup Instrument Nitrogen to the ADS relief valves using SO 16A.1.A-3, "Backup Instrument Nitrogen to ADS Startup and Operation". I will describe initial plant conditions and provide you access to the materials required to complete this task.

F. TASKCONDITIONS/PREREQUISITES

1. The Prerequisites listed in SO 16A.1.A-3 "Backup Instrument Nitrogen to ADS Startup and Operation" are met.
2. Shift Management has determined that COL 16A.1.A-3 "Backup Instrument Nitrogen to ADS System" is not required.

G. INITIATING CUE The Control Room Supervisor directs you to perform steps 4.2 through 4.S of SO 16A.1.A-3 "Backup Instrument Nitrogen to ADS Startup and Operation" in order to lineup Backup Instrument Nitrogen to the Unit 3 ADS relief valves using all three bottles. PLOR271 P RevOOO Page 3 of 6

H. PERFORMANCE CHECKLIST II STEP NO STEP ACT STANDARD 1 Obtain a copy of procedure SO 16A.1.A-3. P A copy of procedure SO 16A.1.A-3 is obtained. N01*E *** 

                                              *** N01'E HV-3-1SA-33331A (B, C) are OPEN per the Check Off List. SO 1SA.1.A-3 does not mention these valves as they are assumed to be in the COL position. If the candidate asks the position of these valves, report that they are OPEN lAW the COL. Note that the COL is available and may be provided to the candidate on request.
     *2  Open or verify open nitrogen bottle            S   HV-3-16A-33153A position is checked by 3AS377 Block Valve.                               attempting to turn handwheel in the close direction, then valve is opened by turning (Cue: If handwheel turned Clockwise,               handwheel slowly in the counterclockwise valve will not turn (Valve is CLOSED).             direction.

When handwheel turned counterclockwise, inform candidate valve is OPEN.) 

     *3  Open or verify open nitrogen bottle            S   HV-3-16A-33153B position is checked by 3BS377 Block Valve.                               attempting to turn handwheel in the close direction, then valve is opened by turning (CUE~: If handwheel turned Clockwise,             handwheel slowly in the counterclockwise valve will not turn (Valve is CLOSED).            direction.

When handwheel turned counterclockwise, inform candidate valve is OPEN.) 

     *4   Open or verify open nitrogen bottle           S   HV-3-16A-33153C position is checked by 3CS377 Block Valve.                               attempting to turn handwheel in the close direction, then valve is opened by turning (Cue: If handwheel turned Clockwise,              handwheel slowly in the counterclockwise valve will not turn (Valve is CLOSED).            direction.

When handwheel turned counterclockwise, inform candidate valve is OPEN.) PLOR271 P RevOOO

STEP NO STEP ACT STANDARD 

    *5   Slowly open the nitrogen bottle isolation   S    Nitrogen bottle isolation valves 3A (B, C) valves for 3AS377, 3BS377 and 3CS377.            377 position is checked by attempting to turn handwheel in the close direction, then (Cue: If handwheel turned Clockwise,            valve(s) are opened by turning handwheel valve will not turn (Valve is CLOSED).           slowly in the counterclockwise direction.

When handwheel turned counterclockwise, inform candidate valve is OPEN.) (Cue-: If asked, inform the examinee the individual bottle PCV outlet pressure indicators (left-side gauge) and header pressure indicator (PI-9130) read zero psig. Individual bottle pressures (right-side gauge) indicate 2200 psig.) 

    *6   Adjust nitrogen bottle 3AS377 pressure      S    PCV-3-16A-9917A handle is turned control valve to obtain?: 95 psig.               clockwise until?: 95 psig is obtained on bottle 3AS377 pressure indicator.

(Cue: Acknowledge PCV operation, left side pressure indicator for bottle 3AS377 indicates 95 psig.) 

    *7   Adjust nitrogen bottle 3BS377 pressure      S    PCV-3-16A-9917B handle is turned control valve to obtain;::: 95 psig.            clockwise until;::: 95 psig is obtained on bottle 3BS377 pressure indicator.

(Cue: Acknowledge PCVoperation, left side pressure indicator for bottle 3BS377 indicates 95 psig.) 

    *8   Adjust nitrogen bottle 3CS377 pressure      S    PCV-3-16A-9917C handle is turned control valve to obtain?: 95 psig.            i clockwise until?: 95 psig is obtained on bottle 3CS377 pressure indicator.

(Cue: Acknowledge PCV operation, left side pressure indicator for bottle 3CS377 indicates 95 psig.) 9 Request URO to verify Backup Nitrogen is S Control Room is requested via telephone, 

          ?: 95 psig on PI-9142 located on 30C003         radio, or GAI-TRONICS page system to panE~1.                                         verify that backup nitrogen pressure is
                                                          ?: 95 psig on PI-9142.

(Cue: Unit Reactor Operator acknowledges request and reports that I PI-9142 indicates 95 psig.) I PLOR271 P RevOOO Page

STEP NO STEP ACT STANDARD 10 Inform Control Room Supervisor of task S Task completion reported using telephone, completion. hand held radio, or GAI-TRONICS page system. (Cue: Control Room Supervisor acknowledges report.) 11 As an evaluator ensure that you have P Positive control established. positive control of all material provided to the examinee (Task Conditions! Pren~quisites) AND procedures. Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the Backup Instrument Nitrogen to ADS System has been lined up locally and the LlRO verifies.::: 95 psig Backup Instrument Nitrogen pressure indication, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise. PLOR271 P RevOOO

TASK CONDITIONS/PREREQUISITES

1. The Prerequisites listed in SO 1SA.1.A-3, "Backup Instrument Nitrogen to ADS Startup and Operation" are met.
2. Shift Management has determined that COL 1SA.1.A-3 "Backup Instrument Nitrogen to ADS System" is not required.

INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to perform steps 4.2 through 4.5 of SO 1SA.1.A-3, "Backup Instrument Nitrogen to ADS Startup and Operation" in order to lineup Backup Instrument Nitrogen to the Unit 3 ADS relief valves using all three bottles.

Scenario Outline ES-D-1 Simulation Facility Peach Bottom Scenario No. #1 (new) OpTest No. 2009 NRC Examiners Operators CRS (SRO) URO (ATC) PRO (BOP) Scenario The scenario begins with the reactor at approximately 5% power during a reactor startup. Following Summary shift turnover, the crew is directed to secure drywell purge in preparation for inerting the drywell. Once drywell purge is secured, the crew should continue with the reactor startup by pulling control rods in accordance with the approved startup sequence. During this evolution a control rod will drift out, requiring the crew to execute ON-121 "Drifting Control Rod" and declare the affected control rod inoperable in accordance with Tech Specs. After the actions for the drifting control rod are complete, the 'B' drywell chiller will trip. The crew should place a standby drywell chiller in service in accordance with the system operating procedure. Next, a blown fuse will cause an ARI power supply failure, requiring the crew to initiate repairs and evaluate ARI-RPT operability per Tech Specs. This will be followed by an APRM trip with an auto scram failure, requiring the crew to initiate a manual scram. A SULCV failure will complicate RPV level control post-scram. Following the scram, a leak will develop in the torus, requiring the crew to enterT-103 "Secondary Containment Control" and T-102 "Primary Containment Control". A failure of the turbine bypass jack will require the crew to use alternate methods to depressurize the reactor in accordance with T-101 "RPV Control". Torus level will continue to lower to the point where the crew will be required to perform T-112 "Emergency Blowdown". Initial IC-91, 5% power Conditions Turnover See Attached "Shift Turnover" Sheet Event Malfunction Event Event No. No. Type'" Description 1 N PRO Secure drywell purge CRS 2 R URO Power ascension with control rods CRS 3 C LlRO Drifting contr*ol rod (Tech Spec) TS PRO CRS 4 C PRO Drywell chiller trip I place standby chiller in service CRS 5 TS CRS ARI power supply failure (Tech Spec) 6 I URO APRM trip with auto scram failure I manual reactor scram CRS 7 M ALL Torus leak into secondary containment I emergency blowdown 8 I URO Startup level control valve (LCV-8091) failure CRS 9 C PRO Turbine bypclss jack fails (prevents rapid depressurization to the main CRS condenser) .. (N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec

SIMULATOR OPERATOR INSTRUCTIONS FOR 2009 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

  • This is a new scenario developed for the 2009 NRC ILT Exam.

INITIAL SETUP Initial Conditions

  • IC-91, -5% power (created from IC-9, with rods driven back to Group 12, rod 14-55)
  • Ensure recorder power is on; roll recorders as required
  • Ensure annunciator horns are active Blocking Tags
  • None Activate .APP "2009_NRC_SCN1" or insert the following:

Event Triggers TRG E2 ROD_1455_TOGGLE_SCRAM 

                 =

TRG E2 DMF CRM011455 TRG E6 REACTOR_MODE_SWITCH_IN_SHUTDOWN Malfunctions IMF RPS05 (none 0 0) (RPS automatic scram failure) IMF CRM011455 (E1 00) (Control rod 14-55 drifts out) IMF DCW02B (E3 0 0) ('8' drywell chiller trips) IMF ARIF2B (E4 0 0) ('8' ARI power supply f,ailure - blown fuse) IMF APR01 A (E5 0 30) 130 (APRM 1 upscak~ failure - deactivates after 30 seconds) IMF APR01B (E5 030) 130 (APRM 2 upscale failure - deactivates after 30 seconds) IMF FWC01 D (E6 0 0) 0 (startup LCV AO-8091 fails closed) IMF PCS07 (E7 0 0) 10020:000 (torus leak)

Overrides lOR ZYP01A6A1S17 (none 00) "NO INCR" (fails the Bypass Jack RAISE pushbutton) Trip Overrides None Turnover Procedures

  • GP~2 "Normal Plant Start~Up" complete up to step 6.2.51 o Step 6.2.44 - in process
  • Rod Sequence Sheet is complete up to Group 12, Rod 14~55
  • Control rod withdrawal per SO 62.1.A~2 "Withdrawing/Inserting a Control Rod"
  • SO 6C.1.A-2 C' Reactor Feedwater Pump Startup With Vessel Level Control Established Through AO-8091" up to step 4.4
  • SO 6C.1.C-2 "Startup of Second or Third Reactor Feedwater Pump" up to step 4.5.
  • SO 7B.4.A-2 "Containment Atmosphere De-Inerting And Purging Via SBGT System" at step 4.19
  • SO 1B.1.A-2 "Main Turbine Startup And Normal Operations" at step 4.10
  • OP-AB-300-1 003 Attachment 1 "Reactivity Maneuver Approval Form" at step 1 of 4 covering startup from all rods in to generator synchronization

SIMULA TOR OPERATOR DIRECTIONS EVENT 1 Support the crew as necessary while securing drywell purge. EVENT 2 Support the crew as necessary during control rod withdrawal. EVENT 3 NOTE: the Control Rod Move Sheet requires notch withdrawal of control rod 14-55 from position 16 to position 22. Therefore, for the rod drift malfunction to work properly, it must be inserted BEFORE notch position 18 (e.g., at notch position 16). When control rod 14-55 is notched out, initiate ET1 (lMF CRM011455) to insert a control rod drift malfunction on control rod 14-55. When sent as the Equipment Operator to inspect HCU 14-55, report back by phone or radio that nothing looks abnormal on the HCU. When the scram toggle switch for control rod 14-55 is placed in the DOWN position at Panel 20C016, verify ET2 initiates to delete the control rod drift malfunction (DMF CRM011455). IF the rod drift malfunction is missed on control rod 14-55, insert the malfunction on control rod 46-55, which is the next control rod in the sequence that must be notch withdrawn from position 16 to position 22 (IMF CRM014655). IF the rod drift malfunction was inserted on control rod 46-55, the malfunction must be deleted manually (DMF CRM014655) when the scram toggle switch is placed in the DOWN position. EVENT 4 Initiate a trip of the 'B' Drywell Chiller using ET3 (IMF DCW02B). If an Equipment Operator is dispatched to inspect the 2B Drywell Chiller, report the chiller is shutdown and screen diagnostics indicate a severe power phase unbalance. If an Equipment Operator is dispatched to inspect the 2B Drywell Chiller circuit breaker, report the breaker is tripped on overcurrent. Support placing the 2C chiller in sE~rvice using SO 44A.6.A-2 "Placing An Additional Drywell Chiller In Service". The Equipment Operator will be directed to perform steps 4.4 through 4.9 prior to starting the chiller. EVENT 5 Initiate an ARI power supply failure using ET4 (IMF ARIF2B). If/when directed to check the power supplies and fuses for the 'B' ARI logic channel in the Cable Spreading Room, report fuse BB-F12 in Panel20C019 is blown.

SIMULA SIMULATORTOR OPERA OPERATOR TOR DIRECTIONS EVENT 6 After the crew has made a Tech Spec declaration for the failed ARI power supply, and at the Lead Examiners direction, initiate ET5 (IMF APR01A1B) to cause a momentary (30 second) upscale failure of APRM #1 and #2. When the Mode Switch is placed in SHUTDOWN, verify ET6 initiates (IMF FWC01D) to fail the startup level control valve (AO-8091) closed (see Event #8). EVENT 7 NOTE: TORUS WATER LEVEL OUT OF NORMAL RANGE (226 A-4) will annunciate approximately 1-2 minutes after the leak malfunction is inserted. After the crew has stabilized the plant following the reactor scram (Le., following scram reports), initiate a leak in thl3 torus using ET7 (IMF PCS07 10020:000). If an Equipment Operator is dispatched to determine the source of the torus leak, wait 5 minutes, then report hearing a loud rush of water in the Torus Room and there are several inches of water on the Torus Room floor. EVENT 8 Support the crew as necessary for the startup level control valve (AO-8091) failure. EVENT 9 Role-playas plant staff if asked to investigate why the bypass valves will not open on the manual jack. TERMINATION The scenario may be terminated when the RPV is depressurized and HPSW is injecting into the torus.

SHIFT TURNOVER PLANT CONDITIONS:

  • Unit 2 startup lAW GP-2 "Normal Plant Startup" in progress. Procedure complete up to step 6.2.51.

o 6.2.44 is open (Drywell purge) to support Drywell inspections, which are now complete.

  • Rod Sequence Sheet is complete up to Group 12, rod 14-55.
  • Currently in Step 1 of ReMA PB2C16-1.0.

INOPERABLE EQUIPMENT/LCOs:

  • None SCHEDULED EVOLUTIONS:
  • Continue the Reactor startup in accordance with GP-2
  • Secure Drywell purge per step 6.2.44 of GP-2:, using SO 7B.4.A-2
  • Commence inerting the containment lAW SO 7B.1.A-2 "Containment Atmosphere Inerting" SURVEILLANCES DUE THIS SHIFT:
  • None ACTIVE CLEARANCES:
  • N()ne GENERAL INFORMATION:

After turnover the crew will resume power ascension. GP-2 is complete through step 6.2.51. A Reactivity Briefing was already completed and you are ready to begin withdrawing rods at the beginning of Rod Group 12, control rod 14-55.

  • Control rod withdrawal per SO 62.1.A-2 "Withdrawingllnserting a Control Rod"
  • RE~actor level control is through AO-8091 using SO 6C.1.A-2 (at step 4.4).
  • 2B Reactor Feed Pump is in standby per SO 6C.1.C-2 (at step 4.5).
  • Containment purge is in progress using SO 7B.4.A-2 (at step 4.19).
  • Cilest warming is in progress using SO 1B.1.A-2 (at step 4.10).

NOTE;.: for the purposes of the 2009 NRC Exam, the PRO will secure drywell purge while the URO continues the power ascension (control rod withdrawal). A qualified individual will provide a peer-check during the control rod withdrawal evolution.

CRITICAL TASK LIST

1. Shutdown the reactor by placing the Mode Switch in "SHUTDOWN" OR by depressing the manual scram push buttons when indications of a failure to scram are received.
2. Perform an emergency blowdown in accordance with T-112 "Emergency Blowdown" when Torus level cannot be maintained above 10.5 feet.
3. Secure HPCI in accordance with RRC 23.1-2 "HPCI System Operation During A Plant Event" OR SO 23.2.A-2 "HPCI System Shutdown" when Torus level cannot be maintained above 9.5 feet.

(NOTE: this CT only applies IF HPCI is in service for injection or pressure control, and IF Torus level lowers below 9.5 feet, which is dependent on when HPSW is placed in service to fill the Torus per T-231.)

Operator Actions OpTest No.: 1 Scenario No.: 1 Event No.: 1 Page: 1of12 Event

Description:

Secure drywell purge Cause: N/A Effects: N/A Time Position Applicant's Actions or Behavior CRS Direct drywell purge secured per step 6.2.44 of GP-2, using SO 7B.4.A-2. PRO Secure drywell purge starting at step 4.19 of SO 7B.4.A-2 "Containment Atmosphere De-inerting and Purging Via SBGT System".

  • Place the standby Drywell Purge Fan to OFF
  • Stop the running Drywell Purge Fan
  • Shutdown SBGT using SO 9A.2.B "SBGT System Shutdown Following Manual Start"
  • Close AO-20459 and AO-20460 on panel 20C012
  • Direct EO to verify HCS-00522-1 is OPEN on panel OBC452
  • Close the following valves using SO 7B.7 .A-2:

o AO-2505 o AO-2520 o AO-2506 o AO-2507

  • Close SBGT valves AO-20469-1 and AO-20469-2 on the 20C012 panel NOTE: at the Lead Examiner's direction, step 4.4 of SO 9A.2.B (SBGT lineup for Automatic Operation) may be performed by an "extra" operator.

Operator Action!! ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 2 Page: 20f12 Event

Description:

Power ascension with control rods Cause: N/A Effects: N/A Position Applicant's Actions or Behavior CRS Direct the URO to commence rod withdrawal in accordance with the Startup REMA and the Startup Sequence beginning with Rod Group 12, control rod 14-55. URO Commence rod withdrawal beginning with Rod group 12, Rod 14-55. Withdraw control rods by selecting the rod on the matrix and then using the Single Notch Withdrawal switch to withdraw control rods. Monitor nuclear instrumentation and reactor power during control rod withdrawal. PRO Monitor balance of plant conditions during rod withdrawal. NOTE: the scenario will continue when the Lead Examiner is satisfied with the reactivity manipulation. The rod drift malfunction must be inserted before position 20 (e.g., at position 16).

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 3 Page: 30f12 Event

Description:

Control rod drifts out Cause: Leaking directional control valve on HCU Effects: Uncontrolled reactivity change Position Applicant's Actions or Behavior URO/PRO Acknowledge annunciator 211 (0-4)(D-4) ROD DRIFT and inform CRS of alarm condition and that control rod 14-55 is drifting out. CRS Enter ON-121 "Drifting Control Rod". Direct an Equipment Operator to inspect HCU 14-55. Request Shift Manager to notify Reactor Engineering. URO Per ON-121 "Drifting Control Rod":

  • Select control rod 14-55 on the select matrix.
  • Monitor changes in reactor power, level, pressure.
  • Insert control rod 14-55 to full in position using the Emergency-In control switch and HOLD at the full in position for 30 seconds (perform this step for a total of 5 times since the control rod wi" continue to drift).

NOTE: at the Lead Examiner's direction, the crew can continue with ON-121, step 2.9 (individual rod scram) after 2 attempts at step 2.8.

  • Insert control rod 14-55 to full in position using the Emergency-In control switch and HOLD at the full in position prior to the individual rod scram.
  • After the individual rod scram for control rod 14-55 has been performed, release the Emergency-In control switch.
  • Reset the ROD DRIFT DRI FT alarm when control rod 14-55 is no longer drifting.

PRO Direct an Equipment Operator to inspect HCU 14-55. Perform an individual scram of control rod 14-55 by placing its associated scram toggle switch in the DOWN position on panel 20C016. After 15 seconds, return the toggle switch to the UP position. CRS Refer to Tech Spec 3.1.3 for one inoperable control rod.

  • Determine Condition C applies: fully insert the control rod within 3 hours and disarm the rod drive mechanism within 4 hours.

Operator Actiom! ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 4 Page: 4of12 Event

Description:

        '8' drywell chiller trip I place standby chiller in service Cause:         Spurious chiller motor high temperature Effects:       1. Alarms:
  • 217 D-1 "Drywell Chiller Trouble"
  • 217 J-1 "Drywell Chilled Water Hi-Lo Temp" (approximately 15 minutes after chiller trip, depending on restoration time)
  • 217 J-2"A Drywell Chiller Discharge Hi Temp" (approximately 5 minutes after chilled trip)
2. '8' chiller outlet temperature increases; chilled water supply and return, drywell cooler fan outlet and return, drywell equipment drain sump outlet, and recirc pump motor temperatures all increase. Drywelli temperature and pressure rise accordingly.

Position Applicanfs Actions or Behavior URO/PRO Recognize and report alarm 217'D-1 "Drywell Chiller Trouble" and enter the corresponding Alarm Response Card. Recognize and report alarm 217 J-1 "Drywell Chilled Water Hi-Lo Temp" and enter the corresponding Alarm Response Card, if it alarms. Recognize and report alarm 217 J-2 "A Drywell Chiller Discharge Hi Temp" and enter the corresponding Alarm Response Card. CRS Enter and execute ARC 217 D-1" Drywell Chiller Trouble":

  • Direct placing additional drywell chillers in service lAW SO 44A.6.A-2 "Placing an Additional Drywell Chiller in Service."

NOTE: Drywell chillers are NOT in outage operation.

  • Direct performing SO 44A.7.F-2 "Response to a Drywell Chiller Trouble Alarm."

PRO Place the control switch for the '8' drywell chiller in "STOP". Start the standby drywell chiller lAW SO 44A.6.A-2 "Placing an Additional Drywell Chiller in Service."

  • Direct an Equipment Operator to verify 2C Drywell Chiller is ready for start by performing steps 4.4 through 4.9 of SO 44A.6.A-2.
  • Place the 'C' chilled water pump in service by placing the pump control switch in "RUN".
  • Place the 'C' drywell chiller in service by placing the chiller control switch in "START".

Dispatch an Equipment Operator to perform SO 44.A.7.F-2 "Response to a Drywell Chiller Trouble Alarm."

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 5 Page: 50f12 Event

Description:

ARI power supply failure Cause: 810wn fuse for the '8' ARllogic power supply Effects: 1. Alarm: 207 E-3 "ARI-RPT System INOP/Loss of Power"

2. Automatic and manual initiation of the '8' logic channel is disabled.

Position Applicant's Actions or Behavior URO Recognize and report alarm 207 E-3 "ARI-RPT System INOP/Loss of Power" and enter the corresponding Alarm Response Card. Determine the '8' logic channel is affected by observing the ARI solenoid valve position (green) indicating lights on Panel 20C005A. Dispatch an Equipment Operator to the Cable Spreading Room to check the '8' ARllogic power supply and fuses. CRS Refer to Tech Spec 3.3.4.1 for ARI-RPT Instrumentation.

  • Determine Condition C applies: within 1 hour, restore the inoperable channel to OPERA8LE status.

Refer to TRM 3.1 for ARI Instrumentation.

  • Determine Condition C applies: within 1 hour, restore ARI trip capability.

NOTE: the above application of Tech Specs and TRM is based on losing 125 VDC power to the '13' ARllogic channel, which prevents the ARI function from occurring {both channels must trip for ARI to occur) and prevents the AlWS-RPT function from occurring since both channels must trip for the Recirc MG field breakers to trip (ARI-RPT contacts are in series in the drive motor breaker trip circuit).

Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 1 Event No.: 6 Page: 6of12 Event

Description:

APRM channels 1 and 2 trip with auto scram failure I manual reactor scram Cause: Spurious upscale failure of APRM channels 1 and 2 coincident with RPS failure Effects: 1. Alarms:

  • 211 A-3 "APRM I OPRM HI-HI/INOP"
  • 211 8-5 "APRM HI"
2. Momentary (30 second) APRM upscale condition with scram failure, requiring crew to manually scram the reactor.

Position Applicant's Actions or Behavior LlRO Recognize and report alarms 211 A-3 "APRM I OPRM HI-HI/INOP" and 211 8-5 "APRM HI", and enter the corresponding Alarm Response Card (as time permits). Recognize APRM channels 1 and 2 are upscale high. Recognize and report failure to scram (ATWS): (ATWS): CT

  • Place the mode switch to "SHUTDOWN".
  • Verify I report control rods are inserting.
  • Verify I report APRMs are downscale.
  • Verify all control rods are inserted.
  • When RPV level beuins to recover "Emergency Stop" 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.
  • Establish and maintain RPV level control with feedwater (see Event #8).
  • Verify all control rods are inserted.
  • Verify RPV pressure, trend, and status of EHC.
  • Notify health physics of changing plant conditions.

CRS Enter T-101 "RPV Control" (scram condition with power> 4%). CT

  • Direct placing the mode switch to "SHUTDOWN", as necessary.
  • Direct RPV level restored and maintained between +5 and +35 inches.
  • Direct RPV pressure stabilized below 1050 psig.
  • Direct restoration of drywell instrument nitrogen lAW GP-8.E "Primary Containment Isolation 8ypass".

Operator Actions OpTestNo.: 1 Scenario No.: 1 Event No.: 6 Page: 7 of 12 Event

Description:

APRM trip with auto scram failure I manual reactor scram (continued) Position Applicant's Actions or Behavior PRO Perform applicable scram actions: 

                         *  (Should) trip the main turbine; verify main generator lockout.
  • Verify Group II and III isolations and SBGT system initiation.
  • Verify scram discharge volume vents and drains are closed.
  • Verify Hydrogen Water Chemistry is isolated (already is).
  • Verify recirc pumps are at (or below) 30% speed (already are).
  • Monitor instrument Cilir header pressure and drywell pressure.
  • Report to the CRS instrument air header pressure is greater than drywell pressure.

PRO Bypass and restore drywell instrument nitrogen lAW 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 Dryweilinstrument Nitrogen Bypass Switch 16A-S99 in the "BYPASS" position.

Operator Actions ES-D-2 Op Test fIIo.: 1 Scenario No.: 1 Event No.: 7 Page: 8 of 12 Event

Description:

Torus leak into secondary containment I emergency blowdown Cause: Rupture in the torus shell Effects: 1. Alarms:

  • 224 E-S "Torus Room Flood"
  • 226 A-4 "Torus Level Out Of Normal Range"
2. Torus level lowers and will eventually equalize with the torus room at approximately 7 feet.

Position Applicant's Actions or Behavior PRO Recognize and report alarm 226 A-4 "Torus Level Out Of Normal Range" and enter the corresponding Alarm Response Card. Direct an Equipment Operator to determine the source of the leak. CRS Enter and execute T-10:2 "Primary Containment Control".

  • Direct torus level restored using T-233 "CST Makeup to the Torus Via HPCI Minimum Flow Line".
  • Direct torus level restored using T-231 "HPSW Injection Into the Torus".

(May) enter and execute ON-110 "Loss of Primary Containment". PRO Perform T-233 "CST Mtlkeup to the Torus Via HPCI Minimum Flow Line" as directed.

  • Verify HPCI suction MO-23-017 OPEN.
  • Open HPCI minimum flow MO-23-02S.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 7 Page: 90f12 Event De:scription: Torus leak into secondary containment I emergency blowdown (continued) Position Applicant's Actions or Behavior PRO Perform T-231 "HPSW Injection Into the Torus" as directed.

  • Verify closed MO-10-1548 "Outboard Discharge".
  • Verify 28 and 2D RHR pumps are shutdown.
  • Verify 28 and 2D HPSW pumps are shutdown.
  • Verify closed MO-10-0898 "8 HPSW Hx Out".
  • Verify closed MO-10-089D "D HPSW Hx Out".
  • Verify closed MO-32:-2344 (10-186) "HPSW Loop Cross Tie".
  • OPEN MO-10-174 "HPSW/RHR Em Inner Cross Tie",
  • OPEN MO-10-176 "HPSW/RHR Em Outer Cross Tie".
  • OPEN MO-10-0398 "Torus Hdr".
  • Start a HPSW pump.
  • Throttle MO-10-0348 "Full Flow Test" to maintain HPSW flow below 5,300 gpm.
  • Start a second HPSW pump in the same loop, if needed.
  • Throttle MO-1 0-0348 "Full Flow Test" to maintain HPSW flow below 10,600 gpm.

PRO Recognize and report alarm 224 E-5 "Torus Room Flood" and enter the corresponding Alarm Response Card. CRS Enter and execute T-103 "Secondary Containment Control". Direct an evacuation of the torus room in accordance with GP-15 "Local Evacuation" (make request to Shift Manager). CRS Direct RPV depressuriz,ation using bypass valves lAW T-101 "RPV Control", as required by T-102, step T/L-6 (see Event #9). URO/PRO Recognize and report that torus level is approaching 12.5 feet. Recognize and report that torus level is approaching 10.5 feet.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 7 Page: 10 of 12 Event

Description:

Torus leak into secondary containment I emergency blowdown (continued) Position Applicanfs Actions or Behavior CT CRS When torus level cannot be maintained above 10.5 feet, direct an emergency blowdown. 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.

CT PRO Perform an emergency blowdown by opening 5 ADS SRVs. Report 5 ADS SRVs arE! open. CRS Direct RPV level maintained between +5 and +35 inches using Condensate. URO Maintain RPV level between +5 and +35 inches using Condensate. CRS When torus level drops below 10.5 feet, if any RHR pumps are running, direct all operating RHR. pumps secured. URO/PRO As directed, secure all operating RHR pumps by placing their control switches in "STOP". Recognize and report that torus level is approaching 9.5 feet. CT CRS When Torus level cannot be maintained above 9.5 feet, direct HPCI secured (if running). CT URO/PRO Secure HPCI when Torus level cannot be maintained above 9.5 feet, as directed, using RRC 23.1-2:

  • Verify Aux Oil Pump control switch in "START".
  • Place Vac Pump control switch in "START".
  • Depress and hold "Remote Trip" pushbutton.
  • When turbine speed reaches approximately a RPM, place Aux Oil Pump control switch in "PULL-TO-LOCK"
  • Release the "Remote Trip" pushbutton.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 8 Page: 11 of 12 Event

Description:

Startup level control valve (LCV-8091) failure Cause: Control signal failure Effects: 1. Alarm: 210 H-2 "Reactor Hi-Lo Water Level" (depending on when valve failure is discovered)

2. LCV-8091 fails closed, causing RPV water level to lower.

Position Applicant's Actions or Behavior URO Recognize and report alarm 210 H-2 "Reactor Hi-Lo Water Level" and enter the corresponding Alarm Response Card (as applicable). Recognize and report LCV-8091 has failed closed.

  • Attempt to take manual control of LCV-8091; determine valve does not respond to manual control.
  • Perform the following actions to control RPV level:

o Close MO-8090 "C RFP Bypass". o Take manual control of 'C' reactor feed pump M/A station; adjust RFP speed/discharge pressure to - 100 psig above reactor pressure. o Batch feed the RPV by throttling MO-2149C "C RFP Discharge" . OR o Maintain MO-2149C "C RFP Discharge" at a set throttled position. o Control RFP speed/discharge pressure (relative to reactor pressure) to control feed flow.

Operator Actions OpTest No.: 1 Scenario No.: 1 Event No.: 9 Page: 12 of 12 Event

Description:

Turbine bypass valve jack fails to open bypass valves Cause: Instrument malfunction in the EHC logic card Effects: Reactor depressurization cannot be performed using the bypass jack. Position Applicant's Actions or Behavior URO/PRO Determine and report thE~ bypass jack has no effect on opening the main turbine bypass valves. CRS Direct the URO to lower the pressure regulator setpoint in an effort to depressurize the reactor. URO/PRO Lower the pressure regulator setpoint as directed by the CRS. CRS (May) direct RPV depressurization using HPCI in CST-to-CST mode, SRVs, or other methods per T-101. URO/PRO Depressurize the RPV using SRVs, HPCI in CST-to-CST mode, or other methods, as directed. TERMINATION CRITERIA: The scenario may be terminated when the RPV is depressurized and HPSW is injecting into the torus.

Scenario Outline ES-D-1 Simulation Facility Peach Bottom Scenario No. #2 (new) Op Test No. 2009 NRC Examiners Operators CRS (SRO) URO (ATC) PRO (BOP) Scenario The scenario begins with the reactor at 100°10 power. After taking the shift the crew is required to Summary verify operability of the Startup Source load tap changer due to an earlier thunderstorm. Shortly after this, the running CRD pump will trip, requiring the crew to execute ON-107 "Loss of CRD Regulating Function" and place the standby CRD pump in service. Additional thunderstorms in the area will result in a loss of the SBO line, which will require the CRS to enter and evaluate the TRM. Following this, the 'D' SRV will inadvertently open, requiring the crew to take actions to close the valve in accordance with OT -114 "Inadvertent Opening of a Relief Valve". Power will be reduced in accordance with GP-9-2 "Fast Power Reduction", and the crew will be successful in closing the SRV by lowering reactor pressure in accordance with OT-114. Next, a sustained loss of Stator Cooling will occur, requiring the crew to scram the reactor. An ATWS (electrical) will require the crew to execute T-101 "RPV Control" and T-117 "Level/Power Control". The main turbine will trip several minutes into this event as a result of the loss of Stator Cooling, complicating the crew's efforts to respond to the ATWS and challenging Primary Containment due to SRVactuation. When SBLC is initiated, RWCU will fail to automatically isolate, requiring the crew to manually isolate RWCU. In addition, the crew will not be able to restore normal instrument nitrogen, which will require aligning a backup source of nitrogen to the SRVs to ensure they are available for reactor pressure control. After RPV level has been lowered to control power, the ATWS will be terminated using T-214 "Venting the Scram Air Header". Initial IC-92, 100% power Conditions Turnover See Attached "Shift Turnover" Sheet Event Malfunction Event Event No. No. Type* Description 1 N PRO Verify operability of Startup Source load tap changer CRS I 2 C URO CRD pump trip / place standby CRD pump in service CRS 3 TS CRS SBO line failure (TRM) 4 C PRO SRV inadvertently opens (Tech Spec) / maximize torus cooling TS CRS 5 R URO Fast power reduction / pressure reduction due to SRV failure CRS 6 M ALL Loss of stator cooling water / scram (electric ATWS) 7 I LlRO RWCU fails to isolate on SBLC initiation I manually isolate RWCU CRS 8 C PRO Unable to restore drywell instrument nitrogen I place alternate CRS instrument nitrogen system(s) in service 

 * (N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (TS) Tech Spec

SIMULATOR OPERATOR INSTRUCTIONS FOR 2009 NRC SCENARIO #2 GENERAL REQUIREMENTS

  • Rocorders will be rolled prior to the scenario cmd 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 thl~ examination team.

SCENARIO SOURCE HISTORY

  • This is a new scenario developed for the 2009 NRC ILT Exam.

INITIAL SETUP Initial Conditions

  • IC-92, 100 % power
  • Ensure recorder power is on; roll recorders as required
  • Ensure annunciator horns are active Blocking Tags
    *   '8' EHC pump Activate APP "2009_NRC_SCN2" or insert the following:

Event Triggers TRG E4 = DMF MSS08A (closes the 'A' SRV) Malfunctions IMF PCI01V (none 0 0) (RWCU MO-15 fails to automatically isolate) IMF PCI01W (none 00) (RWCU MO-18 fails to automatically isolate) IMF PCI01X (none 0 0) (RWCU MO-68 fails to automatically isolate) IMF CRH03A (E1 0 0) ('A' CRD pump trip) IMF MAP02F (E2 0 0) (trip of S80-1005) IMF MSS08A (E3 0 0) 50 ('A' SRV fails open) IMF SWC01 (E5 3:00 0) (loss of Stator Water Cooling with a three-minute time delay)

Overrides lOR AN0209RA5 (E5 0 0) ALARM_ON (Stator cooiantlH2 seal oil trouble alarm 220 A-5) lOR AN0208RG5 (E5 1 :300) ALARM_ON (Stator coolant standby pump run alarm 206 G-5) lOR ZYP12A2S25 (none 0 0) AUTOOPEN (Instrument Air to drywell valve in AUTO) lOR ZYP12A2S31 (none 0 0) AUTOOPEN (Instrument Air to drywell valve in AUTO) Remote Functions None Trip Overrides Insert the following to provide an electrical ATWS: MRF ARI01 TO OVERRIDE MRF RPS01TO OVERRIDE MRF RPS02TO OVERRIDE MRF RPS05TO OVERRIDE Batch Files None Turnover Procedures

  • AO 53.2-0 "Equipment Checks After a Thunderstorm" NOTE~: PMS point J61 0 is not available in the simulator (Unit 3 point); point data will be simulated.

SIMULA SIMULATOR TOR OPERA OPERATORTOR DIRECTIONS EVENT 1 Support the crew as necessary to perform AO 53.2-0 "Equipment Checks After a Thunderstorm" . EVENT 2 After AO 53.2-0 is completed, or when directed by the Lead Examiner, initiate ET1 (IMF CRH03A) to trip the 'A' CRD hydraulic pump. If requested to check the breaker for the 2A CRD pump (in the E-12 bus room), report that the breaker has tripped on instantaneous ground overcurrent and relay flag 150G is showing. If an Equipment Operator is dispatched to inspect the 2A CRD pump, report there are no indications of abnormalities at the pump. When asked to perform pre-startup checks for the 2B CRD pump, wait until charging header pressure drops below 940#, or when the Lead Examiner is ready to continue and then report steps 4.1.1 through 4.1.5 are complete lAW SO 3.1. B-2 "CRDH System Startup With The System Filled and Vented". When asked to slowly open HV-2-3-36B, MRF CRH02 OPEN and then report HV-2-3-36B is open. If directed to perform SO 2A.1.C-2 "Operation of the Recirculation Pump Seal Purge System", steps 4.1.1 through 4.1.6 and steps 4.2.1 through 4.2.6, report back that the steps are complete. If directed to perform the subsequent steps of SO 2A.1.C-2 (adjusUverify seal purge flowrate), report back that the steps are complete. EVENT 3 After the 'B' CRD pump is in servic'9, or when directed by the Lead Examiner, initiate ET2 (IMF MAP02F) to initiate a trip of the SBO line. Obtain a copy of ARC 00C893 C-2 "1005/30601 BKRS TRIP" and report "the 1005 breaker is tripped" and "there is a differential overcurrent lockout on transformer 00X019 ... investigating the cause". If contacted as PSD, report there are no known 341 or 351 line faults. If asked, report 191-00 line is energized and available.

SIMULATOR OPERATOR DIRECTIONS EVENT 4 After the TRM requirements have been determined for the SBO Line failure, or when directed by the Lead Examiner, initiate ET3 (IMF MSS08A 50) to cause the 

       'A' SRV to fail open (50%).

When directed, isolate A and Bloop RHR stayfull by entering MRF RHR02A CLOSE and MRF RHR028 CLOSE. After EHC pressure setpoint has been lowered, initiate ET4 (DMF MSS08A) to close the 'A' SRV. If directed to remove 'A' SRV contml power fuses, delay fuse removal until after reactor pressure has been lowered and the SRV has closed. Then, if necessary, contact the control room via telephone and inform them you are ready to remove the fuses. If "Torus Level Out Of Normal Range (226 A-4) becomes a nuisance alarm, MRF AN0203DA4 ALARM_ON to override the alarm on. EVENT 5 Support the crew as necessary for GP-9 "Fast Power Reduction". Role-playas the Power System Director when called. EVENT 6 After the 'A' SRV is closed, or when directed by the Lead Examiner, initiate ET5 to initiate the following sequence of events (times are in minutes):

  • T = 0 - Stator cooiantlH2 seal oil trouble 220 A-5 (lOR AN0209RA5)
  • T = 1.5 - Stator coolant standby pump run 206 G-5 (lOR AN0208RG5)
  • T = 3.0 - Loss of stator cooling (IMF SWC01)

When directed to investigate the Stator Coolant trouble alarm, wait 2 minutes then report "INLET FLOW LOW and INLET PRESSURE LOW are alarming on Panel 20C084; investigating the cause." If asked to report the status of the standby stator cooling pump, report both pumps are running.

SIMULATOR SIMULA TOR OPERATOR DIRECTIONS EVENT 6 Pre-inserted malfunctions (Trip Overrides) will result in an electrical A TWS. (continued} Do not permit the operators to utilize the individual scram test switches on the RPS panels when performing T-213 "Scram Solenoid Deenergization." When the applicant opens the panel, inform him/her that the individual scram switches are all in the down position. When directed, provide support for T-220 as an Equipment Operator. After a suitable delay time, MRF T220_2 CLOSE and report to the control room that HV-2-3-56 is closed. When directed to perform T-221 on Unit 2, wait 10 minutes then MRF T221_1 DEFEAT. After level has been lowered to control power lAW T-240 (-172 to -195 inches) and the APRM downscale lights are lit, then on the lead Examiner'S cue insert control rods using T-214 "Venting the Scram Air Header" (MRF T214 VENT). Report that you have commenced venting the scram air header lAW T-214. EVENT 7 Pre-inserted malfunctions (PCI01V, W, X) will prevent RWCU from automatically isolating when SBlC is initiated. EVENT 8 Pre-inserted failures (overrides) will prevent restoring normal drywell instrument nitrogen. This will prevent all non-ADS SRVs from being used for pressure control and/or depressurization. The crew should align Backup Instrument Nitrogen (bottles) to the ADS SRVs and/or request aligning CAD in accordance with T-261. If directed to perform T-261 , wait 20 minutes then enter MRF T261_1 OPEN. TERMINATION The scenario may be terminated when all control rods have been inserted and reactor level is being controlled ab()ve the top of active fuel.

SHIFT TURNOVER PLANT CONDITIONS:

  • Unit 2 is at 100% power.

INOPERABLE EQUIPMENT/LCOs: 

  * 'B EHC pump out of service for micron filter replacement.

SCHEDULED EVOLUTIONS:

  • Verify 3 SU LTC operability lAW AO 53.2-0 "Equipment Checks After a Thunderstorm".

SURVEILLANCES DUE THIS SHIFT:

  • N(me ACTIVE CLEARANCES:
  *  'B' EHC pump GENERAL INFORMATION:
  • M3intain current power.

CRITICAL T ~'SK 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 dryweU pressure is below 2 psig.
2. Initiate a reactor shutdown by performing one or more of the following:
a. T-214 "Isolating and Venting the Scram Air Header"
b. T -220 "Driving Control Rods During a Failure to Scram"
c. Injecting Standby Liquid Control before torus temperature exceeds 110 degrees F

Operator Action:!! ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 1 Page: 10f14 Event

Description:

Verify 3SU load tap changer operability lAW AO 53.2-0 "Equipment Checks After a Thunderstorm" Cause: Required due to a thunderstorm passing near PBAPS Effects: N/A Position Applicant's Actions or Behavior CRS Direct the PRO to verify 3SU load tap changer operability lAW AO 53.2-0 "Equipment Checks After a Thunderstorm". Verify compliance with Tech Spec 3.8.1 AND 3.8.2. PRO Verify 3SU load tap changer operability lAW AO 53.2-0 "Equipment Checks After a Thunderstorm":

  • Verify LTC Mode Switch for 00X005 transformer in "AUTO" and amber light is illuminated.
  • Place LTC Mode Switch for 00X005 transformer to "MAN."

NOTE: PMS pOint J610 is not available (since it is a U3 point). Direct applicant to raise LTC and when at Tap 8, inform applicant that PMS point J610 is reading 14.2 KV.

  • Place 3SU LTC Control Switch to "RAISE" to raise 00X005 transformer voltage in 1 tap increments until transformer voltage is approximately 14.2 KV.
  • Verify transformer voltage taps up from the original tap position.
  • Place 3SU LTC Mode Switch to "AUTO" and verify 00X005 transformer voltage taps down.
  • Verify 3SU bus voltage is between 13.68 KV and 14.35 KV.

NOTE: inform applicant that PMS point J610 is reading 13.8 KV.

  • Verify LTC Mode Switch for 00X005 transformer in "AUTO" and amber light is illuminated.

URO Monitor plant parameters/assist as directed.

Operator Action!!! ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 2 Page: 2of14 Event

Description:

Trip of the 'A' CRD pump Cause: Circuit breaker trips due to a phase-to-phase short Effects: 1. Alarms:

  • 211 F-1 "A CRD Water Pump Trip"
  • 211 F-2 "A CRD Water Pump OVLD"
  • 211 G-5 "CRD Hydraulic Hi Temp" (depending on CRD restoration time)
2. Cooling water, drive water, and motor amps decrease. CRD temperatures rise due to loss of cooling water flow. As accumulator pressure lowers, accumulator trouble lights on the full core display will randomly illuminate.

Position Applicant's Actions or Behavior URO Recognize and report alarms 211 F-1 "A CRD Water Pump Trip" and 211 F-2 "A CRD Water Pump OVLD" and enter corresponding Alarm Response Cards. CRS Enter and execute ON-107 "Loss of CRD Regulating Function". Direct the 'B' CRD pump placed in service per SO 3.1. B-2 "Control Rod Drive Hydraulic System Startup With the System Filled and Vented". Ensure compliance with Tech Spec 3.1.5. Brief/update that when charging header pressure is less than 940 psig, and 2 or more CRD accumulator trouble indicators are lit on withdrawn control rods, then charging header pressure must be restored to ~ 940 psig within 20 minutes, or enter GP-4 "Manual Reactor Scram" URO Place 2A CRD pump control switch to "STOP". Dispatch an equipment operator to check the status of the 2A CRD pump circuit breaker. Dispatch another equipment operator to check the 2A CRD pump, and to perform pre-startup checks of the 2B CRD pump lAW SO 3.1.B-2, step 4.1. Verify CRD flow control valve controller is in "MANUAL" and the valve is closed. URO Recognize and report alarm 211 G-5 "CRD Hydraulic Hi Temp" and enter corresponding Alarm Response Card (depending on CRD restoration time).

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 2 Page: 30f14 Event

Description:

Trip of the 'A' CRD pump (continued) Position Applicanfs Actions or Behavior URO Place the 'B' CRD pump in service per SO 3.1.B-2:

  • Open MO-2-3-20 "Drive Water Pressure" valve.
  • Isolate recirc pump seal purge by closing MO-2-2A-8029 A and B.
  • Start the 2B CRD pLlmp.
  • After CRD flow stabilizes, direct the equipment operator to slowly open HV-2-3-368.

HV-2-3-36B.

  • Return the CRD flow controller to auto lAW step 4.5.
  • Throttle MO-2-3-20 to adjust CRD drive water pressure.

Restore recirc pump seal purge lAW SO 2A.1.C-2 "Operation of the Recirculation Pump Seal Purge System".

  • Direct the Equipment Operator to perform steps 4.1.1 through 4.1.6 (for the 2A pump) and steps 4.2.1 through 4.2.6 (for the 2B pump).
  • Open MO-8029A "8eal Purge Supply" for 2A Recirc pump.
  • Open MO-8029B "S,eal Purge Supply" for 2B Recirc pump.
  • Direct Equipment Operator to adjust/verify seal purge flowrate in accordance with SO 2A.1.C-2.

CRS Direct monitoring recirc pump seal temperatures lAW ON-107. PRO Monitor recirc pump seal temperatures and CRD temperatures, as directed.

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 3 Page: 40f14 Event

Description:

SBO line failure Cause: Differential overcurrent trip of transformer 00X019 Effects: 1. Alarm: 006 G-2 "SBO Circuit Trouble"

2. Trip of the SBO-1005 breaker Position Applicant's Actions or Behavior PRO Recognize and report alarm 006 G-2 "SBO Circuit Trouble" and enter the corresponding Alarm Response Card.

Recognize and report SBO-1005 breaker is tripped. Dispatch Equipment Operator to the SBO switchgear. CRS Review Tech Spec 3.8. 'I, TRM 3.18 and GP-23 "Diesel Generator Inoperable".

  • Per TRM 3.18, determine the SBO (Conowingo) line must be returned to service within 15 days.

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 4 Page: 50f14 Event

Description:

SRV 'A' inadvertently opens Cause: SRV mechanical failure Effects: 1. Alarms:

  • 2100-2 "Safety Relief Valve Open"
  • 227 S-4 "Slowdown Relief Valves Hi Temp"
2. Loss of generator load, steam flow/feed flow mismatch, heat input to the primary containment.

Position Applicant's Actions or Behavior URO/PRO Recognize and report 210 0-2 "Safety Relief Valve Open" and 227 S-4 "Slowdown Relief Valves Hi Temp" and enter the corresponding Alarm Response Cards. CRS Enter/direct actions lAW OT-114 "Inadvertent Opening of a Relief Valve":

  • Lead crew in confirming an SRV is open.
  • Direct torus cooling maximized.
  • Direct attempts to close the 'A' SRV.
  • Direct monitoring torus temperature.

URO/PRO Confirm the 'A' SRV is open lAW OT-114:

  • SRV position indication on Panel 20C003.
  • Generator load reduction.
  • Steam flow - feed flow mismatch (on 'A' MSL).
                           *   "Slowdown Relief Valves Hi Temp" alarm (227 S-4).
  • Rising torus temperature.

PRO Cycle the 'A' SRV control switch when directed. Monitor torus temperature. CRS (May) direct pumping down torus (due to high level) in accordance with SO 14A.1.A-2 "Torus Water Cleanup and Level Control System".

Operator Action~ ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 4 Page: 6of14 Event

Description:

SRV 'A' inadvertently opens (continued) Position Applicant's Actions or Behavior PRO Place the 'A' and 'B' loops of RHR in torus cooling lAW RRC 10.1-2 "RHR System Torus Cooling During a Plant Event" when directed:

  • Open MO-2-10-039A (B)
  • Open MO-2-32-89A (B, C, D)
  • Start A (B, C, D) HPSW pump
  • Start A (B, C, D) RHR pump
  • Open MO-2-10-034A (B)
  • Verify 11,500 to 12,:200 gpm RHR flow
  • Start remaining HPSW pump in A (B) RHR loop
  • Open MO-2-32-89C (B, D)
  • Start remaining RHR pump in A (B) RHR loop
  • Verify >20,000 gpm RHR loop flow
  • Direct Equipment Operator to close stayfull injection valves HV-2-10-70A and HV-2-10-70B.

URO Perform a Fast Power Reduction lAW GP-9-2 when directed (see Event #5). URO/PRO Coordinate removal of fuses by Equipment Operator and monitor valve status during attempts to close the 'A' SRV. CRS Enter T-102 "Primary Containment Control" on high torus temperature (if 95 degrees F is reached). Declare the 'A' SRV inoperable and verify compliance with Tech Spec 3.5.1.F.

  • Determine 'A' SRV must be restored within 72 hours.
  • Review Tech Spec 3.4.3.A and determine no action is required (other than a PTSA).

Depending on torus level and temperature:

  • For high temperature, enter Tech Spec 3.6.2.1 (restore average torus temperature to below 95 degrees F within 24 hours).
  • For high level, enter Tech Spec 3.6.2.2 (restore torus level to less than or equal to 14.9 feet within 2 hours).

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 5 Page: 7of14 Event

Description:

Fast power reduction I pressure reduction due to SRV failure Cause: Directed from OT-114 "Inadvertent Opening of a Relief Valve" Effects: N/A Position Applicants Actions or Behavior CRS Direct a Fast Power Reduction lAW GP-9-2. URO Reduce recirculation flow to 61.5 Mlbs/hr lAW GP-9-2 "Fast Power Reduction." CRS When recirculation flow has been lowered lAW GP-9-2, direct EHC pressure setpoint lowered until PAM pressure is 900 psig. URO Lower EHC pressure setpoint until PAM pressure is 900 psig. PRO Report to the CRS when the 'A' SRV has closed. Maintain the main generator auto-manual voltage regulator balanced (when it alarms). Notify the Power System Director of the required power change. CRS Enter OT-110 "Reactor High Level" if alarm 210 H-2 (Reactor Hi-Lo Water Level) is received during power reduction. When 'A' SRV closes, direct crew to suspend pulling SRV fuses. URO/PRO Direct Equipment Operator to suspend pulling SRV fuses.

Operator Action! ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 6 Page: 8of14 Event

Description:

Loss of Stator Water Cooling / reactor scram / ATWS (electric) Cause: Clogged SWC filter / scram condition with power above 4% due to RPS failure Effects: 1. Alarms:

  • 220 A-5 "2 Gen Stator Coolant or H2 Seal Oil Trouble"
  • 206 G-5 "Stator Coolant Standby Pump Run"
  • 206 L-1 "Generator Protection Circuit Energized"
2. The crew will attempt to initiate a manual scram, and then take actions to terminate the ATWS, as well as control RPV level/power.
3. The turbine will trip in 3.5 minutes since stator amps will be greater than 7760.

Position Applicant's Actions or Behavior PRO Recognize and report 2:20 A-5 "2 Gen Stator Coolant or H2 Seal Oil Trouble" and enter the c:orresponding Alarm Response Card. Dispatch an Equipment Operator to investigate the alarm. URO Recognize and report 2D6 G-5 "Stator Coolant Standby Pump Run" and 206 L-1 "Generator Protection Circuit Energized" and enter the corresponding Alarm Response Cards. CRS Enter/direct actions lAW OT-113 "Loss of Stator Cooling":

  • Lead crew in verifying a valid loss of Stator Cooling condition exists (per OT-113, 206 L-1 in conjunction with 206 G-5 is a valid loss of Stator Cooling).
  • Direct a reactor scrclm per GP-4 "Manual Reactor Scram".

URO Perform GP-4 "Manual Reactor Scram":

  • Reduce recirc flow controllers to minimum (20% demand)
  • Place the mode switch to "SHUTDOWN".
  • Report control rods are NOT inserting.
  • Report APRMs are NOT downscale.
  • Depress both manual scram push buttons.
  • Report T-101 entry due to an ATWS with reactor power> 4%.

Operator Actionl! ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 6 Page: 9 of 14 Event

Description:

Reactor scram / ATWS (continued) Position Applicants Actions or Behavior PRO Perform GP-4 "Manual Reactor Scram" / scram actions:

  • Transfer 13 KV house loads using RRC 53.1-2.
  • Verify Group II & III isolations and SGTS initiation.
  • Verify scram discharge volume vents and drains are closed (only the outboard vents and drains will close due to the RPS failure).
  • Isolate Hydrogen Water Chemistry.
  • Verify recirc pumps are at (or below) 30% speed.
  • Monitor instrument clir header pressure and drywell pressure.
  • Report to the CRS instrument air header pressure is greater than drywell pressure.
  • WHEN the turbine trips (due to the loss of Stator Cooling), verify generator lockout.

CRS Enter/direct actions for T-101 "RPV Control":

  • Verify URO/PRO scram actions.
  • Direct RPV pressure stabilized below 1050 psig using EHC (using SRVs and/or HPCI after the turbine trips).
  • Direct drywell instrument nitrogen restored.
  • Direct actions for the ATWS (see next page).

PRO Attempt to restore drywl311 instrument nitrogen lAW GP-8.E "Primary Containment Isolation Bypass".

  • Place AO-2969A control switch to "CLOSE".
  • Place AO-2969B control switch to "CLOSE".
  • Place Dryweliinstrument Nitrogen Bypass Switch 16A-S100 in the "BYPASS" position.
  • Place Drywell Instrument Nitrogen Bypass Switch 16A-S99 in the "BYPASS" position.

Recognize and report that while attempting to restore drywell instrument nitrogen, the valves did not reopen (see Event #8). CRS Enter T-103 "Secondary Containment Control" as necessary for Torus Compartment High Radiation (per ARC 003 B-1 "2 Unit Reac Bldg Hi Radiation), due to SRV lift following turbine trip.

Operator Action~ ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 6 Page: 10 of 14 Event

Description:

Reactor scram / ATWS (continued) PRO Stabilize RPV pressure below 1050 psig using SRVs and/or HPCI in CST to CST mode for pressure control lAW RRC 23.1-2 Section D:

  • Open MO-2-23-24 "Cond Tank Return".
  • Verify closed MO-2-23-19 "To Feed Line".
  • Start the Vacuum Pump.
  • Throttle OPEN MO-:2-23-21 "Full Flow Test" for 3 to 4 seconds.
  • Simultaneously START Aux Oil Pump AND OPEN MO-2-23-14 "Steam Supply".
  • Verify HPCI system flow rate is 5000 gpm.

CRS Direct T-101 RC/Q actions:

  • Initiation of ARI.
  • Trip recirc pumps at least 10 seconds apart.
  • T-213 "Deenergize Scram Solenoids".

CT

  • T-214 "Vent Scram Air Header" (this direction is critical because it is the only success path to insert control rods during the A TWS).

CT

  • T-220 "Driving Control Rods During Failure To Scram".
  • Enter T-117 "Level/Power Control".

CT

  • Initiation of SBCL.

URO Perform T-101 RC/Q actions when directed:

  • Initiate ARI; report t() the CRS that ARI was NOT successful.
  • Trip recirc pumps at least 10 seconds apart.
  • Direct an Equipment Operator to perform T-213. Attempt LlRO portion of T -213; report to the CRS that T -213 was NOT successful.

NOTE to Examiner: do NOT allow T -213 to be performed. CT

  • Direct an Equipment Operator to perform T-214.

CT

  • Perform T-220.
  • Initiate SBLC in accordance with RRC 11.1-2 "Standby Liquid System Initiation During A Plant Event" (see Event #7).

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 2 Event No.: 6 Page: 11 of 14 Event

Description:

Reactor scram / ATWS (continued) Position Applicant's Actions or Behavior CRS Direct T-117 actions:

  • Inhibit ADS.
  • T-221 "Main Steam Isolation Valve Bypass".

CT

  • Lowering RPV level to below -60 inches by terminating and preventing RPV injection using T-240, Attachment 1, Figure 1.

URO/PRO Perform T-117 actions when directed:

  • Inhibit ADS.
  • Direct an Equipment Operator to perform T-221 to bypass the low level MSIV isolation (-160 inches).

CT Perform T-240 when directed.

  • Terminate and prevent injection using T -240, Attachment 1, Figure 1:

o If HPCI is NOT running, place the Aux Oil Pump in "Pull-to-Lock". o If HPCI is running, place the Aux Oil Pump in "Start", depress and hold the "Remote Trip" pushbutton; when turbine speed reaches -0 rpm, place the Aux Oil Pump in "Pull-to-Lock" and release the "Remote Trip" pushbutton. o Press "Emergency Stop" for all reactor feed pumps. o Press "Slow Raise" or "Fast Raise" for 2 reactor feed pumps. o Close reactor fEted pump discharge valves MO-2149A, B, C. o Verify closed MO-8090 "C RFP Discharge Bypass".

  • Restore RPV injection to control level below -60 inches and within the RPV level band, and using the source, directed by the CRS.

URO/PRO Recognize and report entry into T-102 "Primary Containment Control" due to high Torus temperature of 95 degrees F. CRS Enter and execute T-102:

  • Ensure Torus cooling has been maximized.

Operator Action§ ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 6 Page: 12 of 14 Event

Description:

Reactor scram / ATWS (continued) Position Applicant's Actions or Behavior CRS Direct T-117 actions: CT

  • When Torus temperature reaches 110 degrees F, direct the crew to perform T-240 using Attachment 1, Figure 1, if no SRVs are open; OR Attachment 1, Figure~ 2, if any SRV is open.

CT

  • If not already done, direct initiation of SBLC at or before Torus temperature reaches 110 degrees F (see Event #7).

CT URO/PRO Perform T-240 again, when directed.

  • Terminate and prevent injection using T-240, Attachment 1, Figure 2 (the specific performance steps are listed on page 11).
  • Restore RPV injection when any of the following are reached:

o RPV level reaches -172 inches, or o Reactor power drops below 4%, or o All SRVs remain closed. Control level as directed by the CRS to prevent level from lowering below 

                         -226 inches (2/3 core coverage).

CT URO Recognize "Scram Valve Pilot Air Header Press Lo" (211 0-2) alarm and/or control rods inserting due to T-214 and inform the CRS. Verify all control rods are inserted and inform the CRS. CRS Determine the ATWS is terminated, exit T-117 "Level/Power Control" andenterT-101 RC/L:

  • Direct crew to restore level to +5 to +35 inches.
  • Direct restoration actions.

URO/PRO Restore RPV level to +~; to +35 inches as directed by CRS.

Operator Action§, ES-D-2 OpTest No.: 1 Scenario No.: 2 Event No.: 7 Page: 13 of 14 Event

Description:

RWCU fails to automatically isolate on Group II isolation signal Cause: Isolation logic failure Effects: When SBLC is initiated, RWCU will not automatically isolate, resulting in dilution and removal of boron solution. Operator action will be required in order to isolate RWCU. Position Applicant's Actions or Behavior URO Initiate SBLC, when directed, per RRC 11.1-2:

  • Close Recirc sample valves AO-039 and AO-040.
  • Start 'A' or 'B' SBLC pump.
  • Recognize RWCU diid not isolate.

CT

  • Manually close RWCU valves MO-15, MO-18, and MO-58.
  • Verify SBLC is injecting based on SBLC pump discharge pressure greater than reactor pressure and lowering tank level.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 8 Page: 14 of 14 Event

Description:

Unable to restore drywell instrument nitrogen 1 loss of non-ADS SRVs Cause: Failure of isolation bypass logic Effects: Non-ADS SRVs are not available for reactor pressure control and/or depressurization Position Applicanfs Actions or Behavior CRS Direct alternate methods of supplying nitrogen to the SRVs:

  • Backup Instrument Nitrogen to ADS using SO 16A.7.A-2 o Place SV-8130A and SV-8130B control switches on panel 20C003-03 to RESET and then in AUTO/OPEN.

o Verify open SV-8130A & B. o Verify PI-8142 "Backup N2" on the 20C003-03 panel is?: 85 psig.

  • T-261 "Placing the Backup Instrument Nitrogen Supply From the CAD Tank in Service".

PRO Restore drywell instrument nitrogen as directed.

  • If directed to use Backup Instrument Nitrogen to ADS using SO 16A.7.A-2:

o Place SV-8130A and SV-8130B control switches on panel 20C003-03 to RESET and then in AUTO/OPEN. o Verify open SV-8130A & B. o Verify PI-8142 "Backup N2" on the 20C003-03 panel is?: 85 psig.

  • If directed to perform T-261 "Placing the Backup Instrument Nitrogen Supply From the CAD Tank in Service":

o Verify closed AO-2969B on panel 20C003-03. o Dispatch an Equipment Operator to the CAD Building perform step 4.2 (manual valving). TERMINATION CRITERIA: The scenario may be terminated when all control rods have been inserted and reactor water level is being controlled above the top of active fuel.

Scenario Outline ES-D-1 Simulation Facility Peach Bottom Scenario No. #3 {modified} Op Test No. 2009 NRC Examiners Operators CRS (SRO) URO (ATC) PRO (BOP) Scenario The scenario begins with the reactor at approximately 88% power. Following shift turnover, the crew will Summary perform ST-O-001-200-2 "Turbine Stop Valve Closure and EOC-RPT Functional Test". An RPS failure during the test will require the crew to make a Tech Spec declaration. 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". When this is complete, the 'A' Condensate pump will trip without the expected Recirc System runback. Power must be manually reduced using recirc 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. 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. HPCI will trip shortly after it starts and will not be recoverable. A small reactor coolant leak inside the drywell will be greater than the capacity of RCIC (the only remaining high-pressure feed source) and require the use of containment sprays. The crew should enter T-111 "Level Restoration" and T-102 "Primary Containment Control". A failure of the RCIC flow controller will complicate efforts to feed with RCIC and require the operator to transfer RCIC control to manual. A containment spray logic failure will complicate the crew's efforts to spray containment; the other loop of RHR will be available and should be used to spray containment. 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. Initial IC-93, 88% power Conditions Turnover See Attached "Shift Turnover" Sheet Event Malfunction Event Event No. No. Type* Description 1 N PRO Main Turbine stop valve functional test 1 RPS failure (Tech Spec) TS CRS 2 C URO Service Water pump trip 1 manual start of the standby pump CRS 3 I PRO Orywell pressure instrument fails upscale without the expected half TS CRS scram (Tech Spec) 1 insert half scram lAW GP-25 4 R URO Condensate pump trip with recirc runback failure 1 power reduction CRS 5 M ALL Loss of #2 auxiliary bus 1 loss of condensate & feedwater I reactor coolant leak inside the drywell 6 C URO RPS failure requires ARI to scram the reactor CRS 7 I URO HPCI trip I RelC flow controller fails in automatic (transfer to manual CRS control) 8 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

SIMULATOR OPERATOR INSTRUCTIONS FOR 2009 NRC SCENARIO #3 GENERAL REQUIREMENTS

  • RI3corders 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 is a modified scenario that originated from the 2008 NRC ILT exam. It has been modified and the initial conditions have been altered, als required by NUREG-1021, ES-301.

INITIAL SETUP Initial Conditions

  • IC-93, 88% power, full power rod pattern
  • Ensure recorder power is on; roll recorders as required
  • Ensure annunciator horns are active Blocking Tags
  • None Activate APP "2009_NRC_SCN3" or insert the following:

Event Triggers TRG E5 ARI_A_ARMED TRG E1 = DOR ZAOTC08BPOI4275A_1 TRG E1 = DOR ZAOTC08BPOI4275A_2 TRG E1 = DOR ZAOTC08BPOI4275A_3 TRG E1 = DOR ZAOTC08BPOI4275A_4 TRG E4 = BAT BUS_2_0VERCLIRRENT_LOCKOUT TRG E5 = MRF ARI01TO NORMAL Malfunctions IMF SWS01 B (E1 0 0) ('8' Service Water pump trip) IMF MCS05A (E3 0 0) ('A' condensate pump trip) IMF RRS20 (E4 5:00 0) 0.310:000 (Recirc IlOop rupture at 0.3% severity, 5 minute delay and 10 minute ramp) IMF HPC03 (E6 0 0) (HPCI turbine trips) IMF RCI04 (E6 0 0) (RCIC automatic flow controller fails low)

Oven-ides lOR ZLORP15DS26B (none 0 0) ON (5A-OS26B 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 lOA-17B, prevents containment sprays) lOR AN0205LD4 (E2 00) ALARM_ON (RPS INSTRUMENT GROSS FAILURE - 2100-4) lOR AN0205LF1 (E2 0 0) ALARM_ON (OW HI PRESSURE - 210 F-1) 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 C2 trip) Batch Files (Verify the following Batch File exists - 00 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

  • GP-5 completed through step 5.3.1
  • ST-0-001-200-2 completed through step 6.2.1.34; next step is 6.3.1
  • Provide crew with Key #18 for the turbine stop valve functional test

SIMULA TOR OPERATOR DIRECTIONS EVENT 1 Support crew for main turbine stop valve functional test. During the performance of ST-0-001-200-2 "Turbine Stop Valve Closure And EOC EOC-RPT Functional" provide the crew with the following information (role playas Extra RO at Panels 20C015 and 20C017, allowing the CRS to apply Tech Specs:

  • Step 6.3.7.2 - auxiliary scram relay 5A-K10A did de-energize.
  • Step 6.3.7.3 - auxiliary scram relay 5A-K10B did not de-energize.
  • Step 6.3.7.4 - indicating light 5A-DS26B is lit.
  • Step 6.3.8.1 - auxiliary scrclm relay 5A-K1 OA did energize.
  • Step 6.3.8.2 - auxiliary scram relay 5A-K10B remained energized.
  • Step 6.3.8.3 - indicating light 5A-DS26B is lit.

EVENT 2 After the Tech Spec evaluation is complete, initiate ET1 (IMF SWS01 B) to trip the 

       'B' Service Water pump.

When ET1 is initiated, verify the following overrides are deleted (they were put in to setup the proper conditions for Event #1):

  • DOR ZAOTC08BPOI4275A_1
  • DOR ZAOTC08BPOI4275A_2
  • DOR ZAOTC08BPOI4275A_3
  • DOR ZAOTC08BPOI4275A_4 When requested to check the 'B' 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. Support the crew while restoring the Fuel Pool Service Water booster pumps lAW SO 19.1.A-2, section 4.2. EVENT 3 For the drywell pressure instrument failure. initiate ET2 and verify the following:

  • lOR AN0205LF1 ALARM_ON. DW HI PRESSURE (210 F-1)
  • lOR AN0205LD4 ALARM_ON, RPS INSTRUMENT GROSS FAILURE (210 D-4)

When requested to check the 2AC065D and 2BC065D instrument racks. report Drywell 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.

SIMULA TOR OPERATOR DIRECTIONS EVENT 4 After the crew has inserted a half scram on RPS channel A 1 and before inserting a PCIS channel trip, initiate a trip of the 'A' condensate pump using ET3 (lMF 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. Support the crew as necessary during the power reduction. EVENT 5 Initiate ET4 (BAT BUS_2_0VERCURRENT_LOCKOUT) to cause an overcurrent lockout on #2 aux bus. Verify a Recirc loop rupture initiates 5 minutes later at 0.3% severity on a 10 minute ramp (lMF RRS20 0.3 10:00). If asked, report DWCW return header pressure is 28 psig. After torus sprays are initiated (see Event #8), increase the size of the recirc leak to 3% on a 10 minute ramp (MMF RRS20 310:00). EVENT 6 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. When directed, perform T-221 by floin9 to the Remote Function Index under TRIP Procedures and MRF T221_1 DEFEAT. WAIT 10 minutes then report to thE~ MCR via telephone that the jumpers for T-221 (step 4.1) have been installed. EVENT 7 After HPCI automatically starts (or is manually started), and as soon as RPV level begins to turn, initiate ET6 and verify the following:

  • IMF HPC03 (HPCI turbine trips)
  • IMF RCI04 (RCIC automatic flow controller fails low)

When directed to investigate the HPCI turbine trip, wait 5 minutes and then report unable to determine the cause of the trip.

SIMULATOR SIMULA TOR OPERATOR DIRECTIONS EVENTS Pre-inserted instrument failures will prevent the crew from spraying the torus or the drywell. After the crew attempts to spray containment, delete the override on the OPPOSITE RHR LOOP:

  • To delete the override on the 'B' RHR Loop, DOR ZYP12A3S19
  • To delete the override on the 'A' RHR Loop, DOR ZYP12A1S19 TERMINATION The scenario may be terminated after the RPV has been depressurized and level has been recovered and is controlled.

SHIFT TUR.NOVER PLANT CONDITIONS:

  • Unit 2 is steady at 90% power.
  • A load drop was been performed in preparation for ST-0-001-200-2.
  • G P-5 "Power Operations" is in progress, complete through step 5.3.1.

INOPERABLE EQUIPMENT/LCOs:

  • None SCHEDULED EVOLUTIONS:
  • PE~rform ST-0-001-200-2.
  • R'3ise power to 100% once Reactor Engineers provide ReMA guidance.

SURVEILLANCES DUE THIS SHIFT:

  • Perform ST-0-001-200-2 "Turbine Stop Valve Closure and EOC-RPT Functional".

o The ST has been started and is complete through step 6.2.1.34. o Continue the Turbine Stop Valve functional test beginning at step 6.3.1. o An extra RO is available to perform steps 6.3.7.2 through 4, and 6.3.8.1 through 3. (Provide KEY #18 to the crew during turnover.) ACTIVE CLEARANCES:

  • Ncme GENERAL INFORMATION:
  • Power was lowered to 90% in accordance with GP-5 "Power Operations" under the Reactor Engineers guidance to perform ST-0-001-200-2. The Reactor Engineer will provide a ReMA for returning to full power following the com pl,etion of ST 001-200-2.

CRITICAL TASK LIST

1. Rc!cognize 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 Cllntrol" 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 RPV water level cannot be restored j:lnd maintained above -172 inches.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 1 Page: 1 of 15 Event

Description:

Perform the turbine stop valve functional test Cause: N/A Effects: N/A Position Applicant's Actions or Behavior CRS Direct the PRO to perform ST-0-001-200-2 "Turbine Stop Valve Closure and EOC-RPT Functional", beginning at step 6.3.1. PRO Perform ST-0-001-200-2 Turbine Stop Valve Closure and EOC-RPT Functional":

  • Review ST
  • Inform the Unit Reactor Operator that the test is going to be conducted and what indications can be expected (this may be covered during turnover and/or a CRS briefing).
  • At Panel20C015 and 20C017:
1. Verify all RPS 'A' and 'B' scram solenoid group 1-4 lights are lit.
2. Verify A1 and B1 TURB STOP VALVE NORMAL lights are lit.
  • At Pane120C008B, place the Cv/SV test selector switch to "SV TEST".
  • Verify the lights on all four TSV test buttons are ON.
  • At Panel 20C015. place the EOC-RPT test switch in "TEST" (using KEY #18).
  • Verify alarm 214 D-:3 SYSTEM I EOC-RPT LOGIC PWR FAILITEST.
  • At Pane120C008B. depress and hold TSV-1 test pushbutton.
1. Verify TSV-1 position indicator moves smoothly at low speed to less than 10% open and then fast closes.
2. After 2 to 3 seconds at full close, release the test pushbutton.
3. Verify TSV-1 valve position indicator moves smoothly from closed to full open.
  • When the RPS relay failure is reported. STOP the functional test.
1. Place the CV/SV test selector switch to "OFF".
2. Verify the lights on all four TSV test buttons are off.
3. Place backup EHC pump to "STOP", then back to "AUTO".

URO Monitor plant parameters/assist as directed.

Operator Action!! ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 1 Page: 20f15 Event

Description:

RPS failure during turbine stop valve functional test Cause: Turbine stop valve position switch input to RPS logic fails Effects: RPS instrumentation failure; application of Tech Specs Position Applicanfs Actions or Behavior NOTE: the "Extra RO" at Panels 20C015 and 20C017 (role-played by the Simulator Operator in the booth) will provide the crew with the following information from ST-O-001-200-2, allowing the CRS to apply Tech Specs:

  • Step 6.3.7.2 - auxili,3ry scram relay 5A-K10A did de-energize.
  • Step 6.3.7.3 - auxiliary scram relay 5A-K10B did not de-energize.
  • Step 6.3.7.4 - indicating light 5A-DS26B is lit.
  • Step 6.3.8.1 - auxiliary scram relay 5A-K10A did energize.
  • Step 6.3.8.2 - auxiliary scram relay 5A-K10B remained energized.
  • Step 6.3.8.3 - indicating light 5A-DS26B is lit.

PRO Stop the functional test when the RPS failure is reported. Perform system restoration lAW ST-O-001-200-2, step 6.7 (see previous page). CRS Direct stopping the functional test and system restoration when the RPS failure is reported. Review Tech Spec 3.3.1.1 and determine Condition A applies (RPS Function 8 on Table 3.3.1 1-1):

  • Place associated channel (or trip system) in trip within 12 hours, OR
  • Reduce thermal power to <29.5% RTP within the next 4 hours.

Review Tech Spec 3.3.4.2 and determine Condition A applies:

  • Restore EOC-RPT instrumentation, or place channel in trip, within 72 hours, OR
  • Apply COLR limits of Tech Spec LCOs 3.2.1, 3.2.2, and 3.2.3 for inoperable EOC-RPT, OR
  • Reduce thermal power to <29.5% RTP within the next 4 hours.

Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 3 Event No.: 2 Page: 30f15 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 URO/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. 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 SE~rvice Water pump in service lAW SO 30.1.A-2 "Unit 2 Service Water System Normal Operations". 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).

Operator Action~ ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 2 Page: 4of15 Event

Description:

     'B' Service Water pump trips on overcurrent (continued)

Position Applicant's Actions or Behavior CRS Direct placing the 2A and 2B Fuel Pool Service Water booster pumps in service lAW SO 19.1.A-2 "Fuel Pool Cooling System Startup and Normal Operations" . PRO Place the 2A and 2B Fuel Pool Service Water booster pumps in service lAW SO 19.1.A-2 as follows:

  • Direct an Equipment Operator to prepare the 2A and 2B Fuel Pool Service Water booster pumps for start lAW SO 19.1.A-2, steps 4.2.4 and 4.2.5.
  • Start the 2A Fuel Pool Service Water booster pump by placing the pump control switch in "Run".
  • Start the 2B Fuel Pool Service Water booster pump by placing the pump control switch in "Run".
  • Direct an Equipment Operator to adjust differential pressure for the 2A and 2B Fuel Pool Service Water booster pumps lAW SO 19.1.A-2, step 4.2.8.

CRS Request troubleshootin!~/technical assistance through the Shift Manager.

Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 3 Event No.: 3 Page: 50f15 Event

Description:

Drywell pressure instrument fails upscale without the expected half scram Cause: PIS-2-5-12A fails upscale (gross failure) Effects: Alarms:

  • 210 F-1 "Drywell Hi Pressure Trip"
  • 2100-4 "RPS/PCIS Trip Units in Calibration of Gross Failure" Drywell pressure instrument fails high (gross failure); RPS half scram fails to occur.

Position Applicanfs Actions or Behavior URO Recognize and report the following alarms and enter the corresponding Alarm Response Cards:

  • 210 F-1 "Drywell Hi Pressure Trip"
  • 2100-4 "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. CRS Enter and execute the Alarm Response Cards for 210 F-1 and 210 0-4. Direct an Equipment Operator to check the 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. 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 hours, OR
  • Be in Mode 3 within the next 12 hours.

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 hours, OR
  • Be in Mode 3 in the next 12 hours and in Mode 4 in the next 36 hours.

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 hours, OR
  • Take the compensatory actions for Condition C.

Recognize that RPS/PCIS trips must be installed within 12 hours.

Operator Action:!! ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 3 Page: 6of15 Event

Description:

Drywell pressure instrument fails upscale without the expected half scram (continued) Position Applicant's Actions or Behavior NOTE: due to the RPS failure, the Lead Examiner will act as the Shift Manager and direct the crew to perform GP-25 to install the RPS/PCIS trips. 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 Panel 20C015, insert key and place the A 1 Test Keylock Switch to the TEST position.

NOTE: the next event will be initiated before the crew can perform Appendix 5 of GP-25 (PCIS).

Operator Actions OpTestNo.: 1 Scenario No.: 3 Event No.: 4 Page: 70f15 Event

Description:

      'A' Condensate pump trip with automatic Recirc run    back failure I power runback 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 RPV level and requiring manual recirc flow reduction to control RPV level.

Position Applicant's Actions or Behavior URO Recognize and report trip of the 'A' Condensate pump. Recognize and report the 45% Recirc pump runback failed to occur. Recognize and announce entry into the OT-100 "Reactor Low Level":

  • Recognize the RPV water level drop is caused by a lack of makeup capability, requiring power to be lowered with Recirculation.
  • Reduce power by lowering the 'A' and 'B' Recirc pump speed controllers to a speed demand of 45% (NOTE: 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).

Monitor for Thermal Hydraulic Instabilities (THI). CRS Enter / direct actions of ARC 203 E-2 "A Condensate Pump BKR Trip":

  • Direct the URO to Icwer power by lowering Recirc flow manually to 45% speed.

(May) refer to GP-5 "Power Operations" to determine power must be limited to <80% total feE!dwater flow with 2 Condensate and 3 Reactor Feedwater pumps. Enter and direct actions lAW OT-112 "Unexpected/Unexplained Change in Core Flow".

  • Determine position on the PBAPS Power Flow Operation Map.
  • Direct monitoring for Thermal Hydraulic Instability (THI).

(May) enter OT-100 "Reactor Low Level" - no additional actions required. PRO Investigate the cause of the 'A' Condensate pump trip using the applicable alarm response cards. Direct an Equipment Operator to investigate the breaker and pump. Green flag the 'A' Condensate pump control switch.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 5/6 Page: 8of15 Event

Description:

Loss of #2 auxiliary bus (loss of Condensate and Feedwater) I RPS failure requires manual ARI initiation to scram the reactor 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 Voltagt3"
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 RPV 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. URO Recognize and report f;~eactor 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. Report entry into T -101 "RPV Control" for the A TWS condition. CT CRS Recognize a failure to scram condition exists; enter and execute T-101 "RPV Control". For RC/Q:

  • Direct initiation of Allternate Rod Insertion (ARI).

Operator Action!, ES-D-2 OpTest No.: 1 Scenario No.: 3 Event No.: 5/6 Page: 90f15 Event

Description:

Loss of #2 auxiliary bus I RPS failure (continued) Position Applicanfs Actions or Behavior 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 ARt 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.

CRS Execute T-101 "RPV Control". For RC/L:

  • Direct restoring RPV level to +5 to +35 inches with HPCI and RCIC.
  • Direct S8LC initiation to augment RPV level control.

For RC/P:

  • Direct instrument nitrogen bypassed and restored lAW GP-8E.
  • Direct RPV 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.
  • Monitor instrument air header pressure and drywell pressure; report instrument air header pressure is greater than drywell pressure.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 5/6 Page: 10 of 15 Event

Description:

Loss of #2 auxiliary bus / RPS failure (continued) Position Applicant's Actions or Behavior PRO Bypass and restore drywell instrument nitrogen lAW GP-8E, as directed.

  • Place both instrument nitrogen valve control switches to "Close".
  • Place both keylock switches in "Bypass".
  • Place both instrument nitrogen valve control switches to "Open".

NOTE: this activity may be coordinated between the URO and the PRO. URO/PRO Announce an additional entry condition for T-1 01 based on Reactor level below -48 inches. Operate HPCI and RCIC to restore RPV level to +5 to +35 inches (see Event #7). Initiate SBLC, as directed.

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 3 Event No.: 5 Page: 11 of 15 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 dryweU 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":

  • If 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 torus sprays initiated lAW T-204 "Initiation of Containment Sprays Using RHR".

For DWIT:

  • Direct drywell cooling maximized by performing T -223 "OW 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.

Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 3 Event No.: 5 Page: 12 of 15 Event

Description:

Reactor coolant leak inside the drywell (continued) Position Applicant's Actions or Behavior 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",

URO/PRO Monitor T-1 02 parameters (torus temperature, torus level, drywell pressure, torus pressun~, drywell temperature) and provide trends to the CRS as appropriate. URO Maximize drywell cooling by performing T-223 "OW Cooler Fan Bypass". Shutdown drywell cooling fans when directed. PRO Spray the torus in accordance with T-204 "Initiation of Containment Sprays Using RHR" (see Event #8). CT Spray the drywell in accordance with T-204 "Initiation of Containment Sprays Using RHR". URO/PRO Place CAD in service when directed. Monitor RPV level, and report to the CRS RPV level is continuing to lower. NOTE: the crew will also enter T-103 "Secondary Containment Control" due to high main steam tunnel temperatures (points 1 and 16 on TR TR-2 13-139) but there are no substantive actions that are required.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 5 Page: 13 of 15 Event

Description:

Reactor coolant leak inside the drywell (continued) Position Applicant's Actions or Behavior CRS After it is determined RPV 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.
  • When RPV level drops to -172 inches, direct performance of T-112 "Emergency Blowdown".

CT Enter and execute T-112 "Emergency Blowdown".

  • 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. Verify start of all available Core Spray and LPCI pumps. CT Open the 5 ADS SRVs when directed. CT CRS After T-112 is executed, direct RPV injection maximized with all systems, subsystems, and alternate subsystems. After it is determined RPV level can be maintained above -172 inches, exit T-111 and enter T-'I01, RPV Control at step RC/L-1. Direct RPV level restored to +5 to +35 inches with Core Spray/RHR. CT URO/PRO Maximize injection with all systems, subsystems, and alternate subsystems. Restore and maintain R:PV level +5 to +35 inches, as directed.

Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 3 Event No.: 7 Page: 14 of 15 Event

Description:

HPCI trip I RCIC flow controller fails in automatic Cause: Instrument failure Effects: 1. HPCI will trip shortly after initiation and will not be recoverable.

2. RCIC will not have sufficient speed to inject water into the reactor due to the flow controller failure. Operator action will be required in order to inject with RCIC.

Position Applicant's Actions or Behavior URO Recognize and report alarm 221 8-1 "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. URO Recognize RCIC is not injecting following system startup. Respond to the failure by taking manual control of the RCIC flow controller and raising turbine speed. Manually control RCIC turbine speed as necessary to establish and control RCIC injection to the RPV. Report the RCIC flow controller failure and status of RCIC to the CRS.

Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 8 Page: 15 of 15 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 (8) loop of RHR is available). 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. The steps listed below apply to the 8 loop of RHR but alre the same as those for the A loop of RHR, with the exception of the lett,er designations. 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 8-3) are lit.
  • Place keylock switch 10A-S188 in "MANUAL OVERRIDE".
  • Momentarily place switch 10A-S178 in "MANUAL".
  • Open or verify open MO-2-10-398 "Torus Header".
  • Open or verify open MO-2-10-898(D) HPSW Hx Outlet".
  • Verify load on EDG supplying selected pumps is below 1400 KW.
  • Start 8(D) RHR Pump.
  • Start 8(D) HPSW Pump.
  • Close or verify closed MO-2-10-348 "Full Flow Test".
  • Throttle open MO-2*-10-388 "Torus Spray" to obtain 1,000 gpm on FI-FI 2-10-1368.

CT Recognize and report inability to spray the torus (drywell) with the 8 (A) loop of RHR. CT CRS Direct the operator to attempt to spray the torus with the opposite loop of RHR. CT PRO As directed, spray the torus using the opposite loop of RHR in accordance with T-204 "Initiation of Containment Sprays using RHR". TERMINATION CRITERIA: The scenario may be terminated when the RPV has been depressurized and reactor level has been recovered and controlled.}}

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