ML993480343: Difference between revisions

From kanterella
Jump to navigation Jump to search
(Created page by program invented by StriderTol)
(StriderTol Bot change)
 
(33 intermediate revisions by the same user not shown)
Line 2: Line 2:
| number = ML993480343
| number = ML993480343
| issue date = 11/15/1999
| issue date = 11/15/1999
| title = Operator Licensing Examination Administered Septmber 13-20,1999 at DAVIS-BESSE, Docket NO.50-346
| title = Operator Licensing Examination Administered Septmber 13-20,1999 at DAVIS-BESSE, Docket NO.50-346
| author name = Bies M A
| author name = Bies M
| author affiliation = NRC/RGN-III
| author affiliation = NRC/RGN-III
| addressee name =  
| addressee name =  
Line 16: Line 16:


=Text=
=Text=
{{#Wiki_filter:UNITED STATES NUCLEAR REGULATORY COMMISSION REGION III 801 WARRENVILLE ROAD LISLE, ILLINOIS 60532-4351 November 15, 1999 NOTE TO: FROM:
{{#Wiki_filter:}}
 
==SUBJECT:==
NRC Document Control Desk Mail Stop 0-5-D-24'I Mary Ann Bies, Licensing Assistant I Operations Branch, RIII OPERATOR LICENSING EXAMINATION ADMINISTERED SEPTMBER 13 -20,1999, AT DAVIS-BESSE, DOCKET NO. 50-346 During September 13 -20, 1999, Operator Licensing Examinations were administered at the referenced facility.
Attached, you will find the following information for processing through NUDOCS and distribution to the NRC staff, including the NRC PDR: Item #1 -a) Facility submitted outline and initial exam submittal, designated for distribution under RIDS Code A070.b) As-given operating examination, designated for distribution under RIDS Code A070.Item #2 -Examination Report with the as-given written examination attached, designated for distribution under RIDS Code IE42.Attachments:
As stated i I A D L_-_1 Cv 0Y 1OU FINAL AS-ADMINISTERED OPERATING TEST FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13, 1999 ,-0 7 o FINAL AS-ADMINISTERED ADMINISTRATIVE JPMS FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13,1999 ES-301 Administrative Topics Outline Form ES-301-1 Facility:
Davis Besse Nuclear Power Station Date of Examination:
9/13/1999 Examination Level (circle one): RO / SRO Operating Test Number: (Post NRC Review)Administrative Describe method of evaluation:
Topic/Subject
: 1. ONE Administrative JPM, OR Description
: 2. TWO Administrative Questions A.1 Control of (1) Stroke timing of a Locked Valve.Locked Valves Surveillance (1) Perform compensatory calculations for inoperable computer Requirements alarms for axial imbalance and control rod insertion limits.(1) Generate a safety tagout for a Stator Cooling Water Pump with the Nuclear Operations Management System (NOMS)unavailable.
(1) Check out a radiation detector in the RRA (1) Given dose assessment data, determine the appropriate protective action recommendations.
Emergency Protective Action Guidelines I
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: Al-1 Rev. 00 Page 1 of 7 TASK NO.: 006-003-01-0403 TASK DESCRIPTION:
Perform Administrative Actions for Control of Locked Valves During Post Maintenance Valve Testing of HP 31 K/A
 
==REFERENCE:==
 
GEN 2.1.18 APPLICABLE METHOD OF TESTING: Actual Performance Simulator TIME FOR COMPLETION:
APPLICABILITY:
[XI RO 20 minutes[XI SRO TASK STANDARDS:
1.2.3.Documentation of HP 31 stroke test.Properly complete the Locked Valve Log Sheet.Notify the SS or Control Room SRO when restoration is complete.REOUIRED MATERIALS:
0 00 DB-PF-03272, Post Maintenance Valve Test, Revision Copy of a M&TE data sheet for a VOTES test rig Pump and Valve Basis Document, Vol. III 1, Change 3 GENERAL
 
==REFERENCES:==
 
DB-PF-03272.
Post Maintenance Valve Test, Revision 1, Change 3 DB-OP-00008, Operation and Control of Locked Valves, Revision 1, Change 3 INITIAL CONDITIONS:
Maintenance has just completed packing adjustment on valve HP 31, HPI Pump 2 Recirc Stop Check Valve, to stop packing leakage per Work Order 99-003466-000. Electricians have installed VOTES testing equipment and are standing by with an equipment operator in the #1 ECCS Room. The Shift Supervisor has brought the Locked Valve Log to the Control Room.INITIATING CUES: The Shift Supervisor has given his permission to stroke HP 31, HPI Pump 2 Recirc Stop Check Valve, and directs you to perform post maintenance valve testing of HP 31 in accordance with DB-PF-03272, Post Maintenance Valve Test.(Hand a copy of DB-PF-03272, and Measure and Test Equipment Traveler to the examinee.)
JPM Al-1 Page 2 of 7 INITIAL CONDITIONS:
Maintenance has just completed packing adjustment on valve HP 31, HPI Pump 2 Recirc Stop Check Valve, to stop packing leakage per Work Order 99-003466-000. Electricians have installed VOTES testing equipment and are standing by with an equipment operator in the #1 ECCS Room. The Shift Supervisor has brought the Locked Valve Log to the Control Room.INITIATING CUES: The Shift Supervisor has given his permission to stroke HP 31, HPI Pump 2 Recirc Stop Check Valve, and directs you to perform post maintenance valve testing of HP 31 in accordance with DB-PF-03272, Post Maintenance Valve Test.
JPM Al -I Page 3 Of 7 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Perform administrative actions for control of locked valves during post maintenance valve testing of HP31.INITIAL CONDITION:
Any time in life or power.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
Ensure the Pump and Valve Basis Document and the Locked Valve Log are available.
Close the breaker for HP 31, BF1194 on Fl1E, IRF BF31A TRUE.MALFUNCTIONS/FAILURE TO INSERT: None.ACTION/CUES:
: 3. HP31 is open.Electricians are ready for you to stroke HP31.6. HP31 is closed.8. Electricians are ready for you to stroke HP31.
JPM Al-1 Page 4 of 7 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Review the procedure.
STANDARD:
Reviews the procedure.
CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Records known data on Attachment 3, Test Record, Parts I, and II.STANDARD: NOTE: Part I complete using Pump and Valve Basis Document, Vol. III: MWO Number = 99-003466-000 OPERATOR = MOV CTMT ISO = NO MAXIMUM STROKE OPEN TIME = N/A MAXIMUM STROKE CLOSE TIME = 42.90 FAIL-SAFE POSITION = N/A Part II, columns 2-3 completed using M&TE data sheet.Stroke times will be obtained from the Pump & Valve Basis Document.COMMENT: Sign and date test data sheets for SRO concurrence (Part I, Column 10, Part II, Column 3).CUE: (If asked) The Shift Supervisor has reviewed the Test Requirements Sheet and no special requirements exist.SAT UNSAT 3. PERFORMANCE STEP: Verify HP 31 is open.STANDARD: Observe Red light ON and Green light OFF. Communicate with the Equipment Operator to determine local valve position.CUE: None.SAT UNSAT JPM Al-1 Page 5 of 7 4. PERFORMANCE STEP: Enter valve data on the Locked Valve Log Sheet and.C. obtain approval to position HP 31 from the Control Room SRO.STANDARD: Enter the following Change From Normal Position data on the Locked Valve Log Sheet and obtain approval to position HP 31 from the Control Room SRO:-Valve/Component Number =HP31-Normal Position = OPEN-Reason for Change = DB-PF-03272
-Elec/Pneu
= checked-SS Permission
= initialed-Time & Date = current COMMENT: This step may be performed any time prior to stroking HP 31.Initial in block labelled "SS Permission" and enter the time and date in the next block.CUE: None.SAT UNSAT 5. PERFORMANCE STEP: Stroke and time HP 31 closed..C.STANDARD: Press the close pushbutton and release.and Green light goes ON.Red light goes OFF COMMENT: VOTES equipment will determine the stroke time.CUE: (If asked) The electrician will provide the stroke time later when the work package is brought to the Control Room.SAT UNSAT 6. PERFORMANCE STEP: Verify HP 31 is closed.STANDARD:
Observe Control Room indications of valve position.Communicate with the Equipment Operator to determine local valve position.CUE: None.SAT UNSAT JPM Al-1 Page 6 of 7 7. PERFORMANCE STEP: Enter the valve position in the 'Position To" block of.C........
the Locked Valve Log and initial in the "positioned By" block.STANDARD:
Enter the valve position "closed" and initial.COMMENT: It is acceptable to complete the log entry after stroking the valve in both directions.
CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Stroke and time HP 31 open..C.STANDARD:
Press the open pushbutton and release. Green light goes OFF and Red light goes ON.COMMENT: VOTES equipment will determine the stroke time.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Initial the "Restored By" block under "Restoration To.C ........ Normal Position" in the Locked Valve Log.STANDARD:
Initial in the appropriate block.COMMENT: It is acceptable to complete both Locked Valve Log entries after stroking the valve in both directions.
CUE: None.SAT UNSAT 10. PERFORMANCE STEP: Complete the "Valve Position Indicator Lights Verified" blocks and record the as-left position in the Valve Restoration Position of the Test Record Part II data sheet.STANDARD:
Complete the specified blocks of the Test Record.CUE: (If asked) The Shift Supervisor wants HP31 to remain OPEN.SAT UNSAT, TERMINATING CUES: This JPM is complete.END TIME JPM Al-1 Page 7 of 7 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ RO [] SRO [ ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date A e.^^rnp~a trttvVt T.nA, 14PP Year Page Db-OP-0000O Change From Normal Positior: Shift Supervisor NalvS/ Hormal Reason For Positlon Chanot Elea/ LW eomponent Swser Position Pneu L It AS 138, CC 609. or WO 19, Refer to Attachment 4.1 > M tV Atl.rmal Position Operator Operator 2nd Oper Shift Supervisor
_1 ---oel Roll. S5 Trim Position Positioned Restored Restoration SS Revelw. fle Valve S. &ock Isol parsdsslon Data 'N By by IV~d By Dat Dat_ _ S Cl7 e___ -.- I-.-- 1-4-1-t I i_I -_ I -i i i i_1I4 I I-i I t I__I______
i _ I-- --I I -_II _- I I .+ I .-._____-_ I -I i t t 1 I _I_- .-I I -tII._ _ _ _i 1 I _ I_---I I 1 Completed Sheet Reviewed By Operations superintendent Date _
teyi PART I -TEST PACKAGE 1- I I Il IViA1t S VALVE NUtBER (3.1.1)A1/A NtUBER (3.1.2)if-o60 6l-I'lo OPERATOR (3.1.3)(WFV, AOV)CFT ISO (3.1.4)--,t-STROKE OPEN 1ME (SEC).'q I f;MAXCLMJ STROKE CLOSE TIn5 (SEC)fv 1 hE FAIL-SAFE POSITION (3.1.7)trnPwN/rtrncE)
IJD-vr-fvv'J.
LINEUP ATTACHED (3.1.9)(VFYlNm)PREPAR SIGNATURE (3.1.10)CONCURRlE SIGNATURE/, DATE (3.1.11)I_ (WSL, MAN) I k xzz/ I iq) I .)1.OJ.L -U) I .% vvr. Aw-, AV/I i _ _ i mo 1 A114-iI I +-I _--I i i -i t t i 9 S;I.I'.Z F--tn B-;Po >O rt M Pl 0 o 9 w0 I-t OW 4'CPI0 0 0 0-!ID-4t.M Ccmrnts: (3.1.8)I iI II Key D PART II -TEST DATA.I Manuall I l CIV Onel Part I l SS l Complete Valve I CompletelPezmissiOfll Cyclel Numberl (3.2.1) l (3.2.3) l (4.1.1)I l kiM I/9 I I I~ 's'I I II .I I I I I I .I I I I'I _ _ _ _ I I I I I I I I I I I I I I _ _ I. I _I I I.I I I I I I I I _ _ I _ _ _I I I I I I I I I Il DB-OP-00016 IlLineup and/orlSpecific TestllRequirements lI Complete I 1 (4.2.1) 1 1 (Initial)
I I I I V A I I I I I I I I I I I .-- , ----- ---- .I Mme) I vrimei I t1rilLial)
I I %-.11 I I I I I : fig I I I I I I I I I I I I Stroke Time (Sec) -Open I Close (4.2.5) 1(4.2.3)(Time) I (Time)_____________
I __________
_ I--- .-I I I _I I _I I I-I--I-IJ I1 Valve Position Indicator Lights Verified Open I Close (4.2.2) 1 (4.2.4)(Initial)
I(Initial I I I I I I I*I I I I I I -I, I I I I I I-1 I I I I I I I Valve I Valve I ValvelStroked FromlFailed tolRestoration
_l Following lFail-Safel Pos'Ition I Stations I Position[
(4.5.1)1 (4.3.1) 1 (4.4.1) I(Open/Close)
I) (List) I(Initial)l (Initial)I .1 I'I A/A I A/,4 I I I@P 'I I I I .I I 1- I I I. .I I I I 'i lI I lI I II i'-3 CA3 j-3 90 It 0 I I I I I I I I-3 0W M j P. I 0 0 P 3 0 O4 p- W i i -- I I I I ; 15 L I -I I I I I I I P V--4 L rt (D P)0 I. .O 0 rr W W 0 F-a I I I I .K %I (3.3.1)-Valve Number: Test Equipment:
M&TE Number: Cal Due Date:_;c / 01 /! / 2 h'AJ n '..
PART III -ACCEPTANCE CRITERIA ACET.C l lACCEPTANCEI lVALVE l CRITERIA 1 llNUM4BER l VERIFIED ll(3.1.1) J (SIGNATURE/DATE)l l l l lI .I lI .I l lI l l l _ _ l l l lI II I l__ I .I I I ACCEPTANCE CRITERIA 2 VERIFIED ACCEPTANCE CRITERIA 3 VERIFIED 1vvrrle n-rc ACCEPTANCE CRIrTRIA 4 VERIFIED ACCEPTANCE CRITERIA 5 VERIFIED I CTCNATh}Rlm
/nATlru'SIGNATURE/DATZ)
I I I+/-U --1uZ,.L/I I ,, _ _ _______II I I I A//A IVb.1 _I J _I I I.1 I I.1 I J.I ; ;-I-I-I-I-I ACCEPTANCE CRITERIA 1. The containment isolation valve was satisfactorily cycled through a minimum of one complete cycle.*2. The stroke time of the motor or air operated valve was less than or equal to the maximum stroke time listed either in Attachment 3 -Part I or attached documentation.
: 3. The valve position indication properly reflects the actual valve stem position.4. For repairs on a control circuit of a containment isolation valve, the valve was cycled one complete cycle from all of its local and remote operating stations.'.3 I1 2 8 P..0f , , I I CO tN .I 0~Pa I 00 toj H W 5. The air operated or solenoid operated valve failed to its safety position listed in Attachment 3 -Part I.*NOTE: A Test Deficiency shall be written if the stroke time exceeds the maximum stroke time listed in Attachment 3 -Part I.w This Test Deficiency resolution shall be approved by the Supervisor
-Test/Performance.
LOCKED VALVE LOG SHEEI Year f Page I DB-OP-0000Q Change From Normal Positior Restoration To Normal Position shift Supervisor Operator Operator 2nd Oper Shift Supervisor VA1v*/ Noroal A.ajon ror Positlon Chanf* ZleI Local Relist SS Time Poitilon Positioned Restored Restoration SS Review Time Coopoflnt valve I. L Nuowber Position Pnleu Lock leol Permission Dat. To by By tVd By Date If AS_13_CCM._or WO_19_ __ _ __ _ _ _ _ --oA_ ___ -,_n 4 if~_ __8 _C0.oW 9 eeiAio~mf~4 Completed Sheet Reviewed By Operations Superintendent Date MEASURING AND TEST EQUIPMENT TRAVELER METS ACTIVITY NUMBER:: 1 of 1 M&TE MPL NO.EEl0 1.1 RELEASE BY HP TECH Joseph Doorman ISSUE-DATE 9/13/99 List every calibration and/or test this M&TE was Functional Checks; identify in comment section.write 'NOT USED'DATE SR/SO/RT/SVI*/ETC.
EQUIPMENT-ID SYS used on. If M&TE was used for GO/NP GO Testing, Troubleshooting, or If No Recordable data is taken write ;NRDT;, if M&TE was Not Used, verification that all uses for the above M&TE have been documented on this traveler The signature below is SSN#RETURNED BY: /-PLEASE DO NOT WRITE ON THE REVERSE SIDE OF THIS FORM DATE:
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: A1-2 Rev. 00 Page 1 of 8 TASK NO.: 015-005-02-0100 TASK DESCRIPTION:
Perform compensatory calculations for inoperable alarms for Axial Power Imbalance and Control Rod Limits.computer Insertion K/A
 
==REFERENCE:==
 
GEN-2.1.19 APPLICABLE METHOD OF TESTING: Actual Performance Simulator or Control Room TIME FOR COMPLETION:
APPLICABILITY:
[XI RO 10 minutes[X] SRO TASK STANDARDS:
: 1. Enter correct data on Attachments 1 and 4.2. Determine the correct operating limits for Attachments 1 and 4.REQUIRED MATERIALS:
DB-NE-03220, Imbalance, Tilt & Rod Index Revision 02 Technical Specifications Calcs -Group 38 Alarms Inoperable, GENERAL
 
==REFERENCES:==
 
DB-NE-03220, Imbalance, Tilt & Rod Index Calcs -Group 38 Alarms Inoperable, Revision 02 Technical Specifications INITIAL CONDITIONS:
Plant is operating at 100% power.EFPD is 350.0 EFPD.Full Incores are operable.INITIATING CUES: Reactor Engineering has informed the Shift Supervisor that the wrong limits were entered in Group 38 for axial power imbalance and control rod insertion making them inoperable.
The Shift Supervisor has directed you to perform DB-NE-03220, Imbalance, Tilt& Rod Index Calcs -Group 38 Alarms Inoperable accordingly.(Hand trainee a copy of DB-NE-03220)
JPM A1-2 Page 2 of 8 INITIAL CONDITIONS:
Plant is operating at 100% power.EFPD is 350.0 EFPD.Full Incores are operable.INITIATING CUES: Reactor Engineering has informed the Shift Supervisor that the wrong limits were entered in Group 38 for axial power imbalance and control rod insertion making them inoperable.
The Shift Supervisor has directed you to perform DB-NE-03220, Imbalance, Tilt& Rod Index Calcs -Group 38 Alarms Inoperable accordingly.
JPM A1-2 Page 3 of 8 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Perform compensatory calculations for inoperable computer alarms for axial power imbalance and control rod insertion limits.INITIAL CONDITION:
100 % power MOL.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
None.MALFUNCTIONS/FAILURE TO INSERT: None.ACTION/CUES:
None.
JPM Al- 2 Page 4 of 8 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C".standards for this item constitutes unless denoted in the "Comments".
Failure to meet any one of these failure. Sequence is assumed START TIME: 1. PERFORMANCE STEP: Identify Attachment 1, Axial Power Imbalance Alarm Inoperable, requiring completion.
STANDARD:
Locate Attachment 1 of DB-NE-03220.
COMMENT: Prerequisites can be completed using initial cue data.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Enter the time.STANDARD:
Correct time entered.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Determine the percent full power source.STANDARD: Determine the source of the percent full power and enter the number 1 through 4 for the corresponding source.COMMENT: Highest NI -Group 38 should be selected four of the six choices is acceptable.
but any of the first CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Enter the percent full power..C.STANDARD: Enter the correct percent full power from the source selected in the previous step.CUE: None.SAT UNSAT JPM Al-2 Page 5 of 8 5. PERFORMANCE STEP: Determine the axial power imbalance source.STANDARD:
Determine the source of the axial power imbalance and enter the number 1 through 4 for the corresponding source.COMMENT: NI Imbalance
-Group 38 should be selected but any of the first four of the five choices is acceptable.
CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Enter the values for the axial power imbalance..C.STANDARD: Enter the correct values for the axial power imbalance from the source selected in the previous step.CUE: None.SAT UNSAT 7. PERFORMANCE STEP:.C.Determine the axial power imbalance limits based on the Core Operating Limits Report and enter them on Attachment 1.STANDARD: Locate figure 4b in the Core Operating Limits Report and enter values of and for the percent full power of _COMMENT: Trainee may use excore limits which are more conservative then incore limits.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Identify Attachment 4, Control Rod/APSR Insertion Alarm Inoperable, requiring completion.
STANDARD:
Locate Attachment 4 of DB-NE-03220.
COMMENT: Prerequisites can be completed using initial cue data.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Enter the time.STANDARD:
Correct time entered.CUE: None.SAT UNSAT JPM A1-2 Page 6 of 8 10. PERFORMANCE STEP: Determine the NI percent full power source.STANDARD:
Determine the source of the NI percent full power and enter the number 1 through 4 for the corresponding source.COMMENT: Highest NI -Group 38 should be selected but any of the first four of the five choices is acceptable.
CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Enter the NI percent full power..C.STANDARD:
Enter the correct NI percent full power from the source selected in the previous step.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Determine the rod position source.STANDARD:
Determine the source of the rod position and enter the number 1 through 4 for the corresponding source.COMMENT: Rod Position -Group 38 should be selected but any of the three choices is acceptable.
CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Enter the values for the rod index.C.C STANDARD:
Enter the correct values for the rod index from the selected source.CUE: None.SAT UNSAT JPM Al-2 Page 7 of 8 14. PERFORMANCE STEP:.C.Determine the rod index limit based on the Core Operating Limits Report and enter them on Attachment 1.STANDARD: Locate figure lb in the Core Operating Limits Report and enter value of _ for the NI percent Full Power of _ .CUE: None.SAT UNSAT 15. PERFORMANCE STEP: Enter the values for the the APSR's Position..C.STANDARD:
Enter the correct values for the APSR's Position from the selected source.CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Determine the APSRs Position limit based on the Core Operating Limits Report and enter them on Attachment 1.STANDARD: Locate figure 3 in the Core Operating Limits Report and enter value of 0%.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM A1-2 Page 8 of 8 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: []RO []SRO []ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date K Cl DB-NE-03220 Revision 02 ATTACHMENT 1: AXIAL POWER IMBALANCE ALARM INOPERABLE Table 1.1 -Imbalance Operability Cross Reference Operable Imbalance Sources Inoperable
-Incores-Group 38 NI Imbalance-NI Imbalance Computer Points-Control Room Indicators
-RPS Voltage Signals Heat Balance Six Minute Calculations Computer-Group 38 NI Imbalance-NI Imbalance Computer Points-Control Room Indicators
-RPS Voltage Signals-NI Imbalance Computer Points-Control Room Indicators
-RPS Voltage Signals-Control Room Indicators
-RPS Voltage Signals COLR Tech.COLR Tech.COLR Tech.COLR Tech.Limits Spec. 3.2.1 Spec. 3.2.1 Spec. 3.2.1 Spec. 3.2.1 Operable Z FP Sources Heat Balance Highest NI Highest NI Highest NI Highest NI I I Attachment 1 Page 1 of 3 DB-NE-03220 Revision 02 ATTACHMENT 1: AXIAL POWER IMBALANCE ALARM INOPERABLE (Continued) 1.0 Prerequisites NOTE 1.1 (TS) I A minimum of three NI Imbalance channels shall l be operable per Technical Specification 3.3.1.1. I 1.1 A source for API measurement and Z FP is operable.2.0 Procedure 2.1 Record what is inoperable and why it is inoperable.
2.2 Record the EFPD.EFPD: I NOTE 2.3 l API shall be determined to be within limits at least ONCE PER HOUR. Repeat Steps 2.3 and 2.4 l at least once per hour until the API alarm is ll declared operable.I_ --- ------------------------2.3 Record on Table 1.2, uVerification of Axial Power Imbalance' the Time, I FP Source, Z FP, API Source, API, and API Limit from the COLR.----------------------------Il NOTE 2.4 (TS) If the API is NOT within the limits refer to I I Technical Specification 3.2.1. I l_ ----- ------------- --------_-2.4 Compare the API to the API limit and initial Within Limits block on Table 1.2.Attachment 1 Page 2 of 3 18 DB-NE-03220 Revision 02 ATTACHMENT 1: AXIAL POWER IMBALANCE ALARM INOPERABLE (Continued)
Table 1.2 -Verification of Axial Power Imbalance ONCE PER HOUR* _AXIAL POWER IMBALANCE FP API** -Limits Within Limits Time Source Z FP Source N15 NI6 NI7 NI8 COLR (Initial)Neg Pos Yes No 71 4  too. / -?0,3D -O lq t os -o58 5_ t '86f~g -}I + g I The order listed below does not necessarily represent any*% FP Sources **API 1. Highest NI -Group 38 1. NI Iml 2. Highest NI -Computer Points 2. NI Iml R795, R804, R814, R820 R794, 3. Highest NI -Validyne Points 3. NI Iml R795, R804, R814, R820 R794, 4. Highest NI -Control Room 4. Contri Indicators
: 5. Highest RPS Voltage Signals 5. RPS Vi 6. Heat Balance The NIs shall be operable per Tech Spec 3/4.3.1.Completed by: y order of preference.
Sources balance -Group 38 balance Computer Points R803, R813, R819 balance Validyne Points R803, R813, R819 ol Room Indicators
'ltage Signals Date Attachment I Page 3 of 3 9 "DB-NE-03220 Revision 02 ATTACHMENT 4: CONTROL ROD/APSR INSERTION ALARM-INOPERABLE Table 4.1 -Rod Insertion Alarm Inoperable Cross Reference Inoperable Heat Balance Six Minute Calculations Computer Operable Rod Position Sources-Group 38 Rod Positions-Rod Group Average Computer Points-Control Room Indicators
-Control Room Indicators
-Control Room Indicators Limits COLR Tech. Spec. 3.1.3.6 Tech. Spec. 3.1.3.9 COLR Tech. Spec. 3.1.3.6 Tech. Spec. 3.1.3.9 COLR Tech. Spec. 3.1.3.6 Tech. Spec. 3.1.3.9 Operable Z FP Source Highest NI Highest NI Highest NI 1 II Z FP Sources 1. Highest NI -Group 38 2. Highest NI -Computer Points R795, R804, R814, R820 3. Highest NI -Validyne Points R795, R804, R814, R820 Rod Position Sources 1. Rod Positions
-Group 38 2. Computer Points CRGs 5, 6 and 7 (Q1 8 8 + Q1 8 9 + Q1 9 0)APSRS: Q191 3. Control Room Indicators
: 4. Highest NI -Control Room Indicators
: 5. Highest RPS Voltage Signal 1.0 Prerequisites 1.1 The sources to be used position, and Z FP are to determine control rod positions APSR operable.2.0 Procedure 2.1 Record what is inoperable and why it is inoperable.
2.2 Record the EFPD.EFPD: tJPo Attachment 4 Page 1 of 3 3~ DB-NE-03220 Revision 02 ATTACHMENT 4: CONTROL RODIAPSR INSERTION ALARM INOPERABLE (Continued)
----l ~NOTE 2.3l (TS) I Control rods and APSRs shall be determined to be l within the insertion limits at least ONCE PER 4 HOURS. Repeat Steps 2.3 through 2.5 until the l Control Rod/APSR Insertion Alarm is declared*I operable.
l l l 2.3 Record on Table 4.2, 'Verification of Rod Index and APSRs', the Time, NI X FP source, Z FP from the highest NI, Rod Position source, RI, Lower RI Limit, APSR position, and Lower APSR Limit. Use the same source for RI and APSR position.IF the same source cannot be used for RI and APSR position list both sources and indicate which is used for each indication.
_ _ _ __ _! NOTE 2.4 (TS) IF the RI is NOT within the limits, refer to ll Technical Specification 3.1.3.6.2.4 Compare the RI to the RI limit and initial the CONTROL RODS, Within Limit block on Table 4.2, "Verification of Rod Index and APSRs5.____________
_ __ _Il ~NOTE 2.5 l (TS) IF the APSRs are NOT within the limits refer to ll Technical Specification 3.1.3.9.2.5 Compare the APSR position to the APSR Limit and initial the APSR, Within Limit block on Table 4.2, 'Verification of Rod Index and APSRs'.Attachment 4 Page 2 of 3 DB-NE-03220 Revision 02 ATTACHMENT 4: CONTROL RODIAPSR INSERTION ALARM INOPERABLE (Continued)
Table 4.2 -Verification of Rod Index and APSRs ONCE PER 4 HOURS*Z Fp Sources **Rod Position Sources I. Highest NI -Group 38 1. Rod Positions
-Group 38 2. Highest NI -Computer Points 2. Computer Points: R795, R804, R814, R820 CRGs 5, 6, and 7 (Q188 + Q18 9 + Q190)3. Highest NI -Validyne Points APSRs: Ql9.1 R795, R804, R814? R820 3. Control Room Indicators
: 4. Highest NI -. Control Room Indicators
: 5. Highest RPS-Voltage Signal The order listed above does not necessarily represent any order of preference.
Completed by: Date__Attachment 4 Page 3 of 3 DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: A2 Rev. 00 Page 1 of 6 TASK NO.: 119-023-03-0100 TASK DESCRIPTION:
Generate a safety tagout for a Stator Cooling Water Pump with the Nuclear Operations Management System (NOMS)unavailable.
K/A
 
==REFERENCE:==
 
GEN-2.2.1 3 APPLICABLE METHOD OF TESTING: Actual performance Classroom or simulator TIME FOR COMPLETION:
33 minutes APPLICABILITY:
[X] RO [XI SRO TASK STANDARDS:
: 1. Identify that Attachment 2 has incorrect isolation boundaries.
: 2. Identify the correct procedure for isolation of the Stator Cooling Water Pump 1 on Attachment 4.3. Enter the correct isolation boundaries on Attachment 7 (see attached).
REOUIRED MATERIALS:
NG-DB-00250, Safety Tagging, Revision 00 and Prepare an Attachment 2 with the following information:
* Equipment Name: Stator Cooling Water Pump 1* Job No.: 99-003299-000
* Work Group: Mechanical Maintenance
* Description of Work: Replace the mechanical seal on Stator Cooling Water Pump 1* Requirements:
Check "Isolate Electrically," "Isolate Mechanically,""Vented," "Drained" and "Other." In the space under "other" enter: Y 01 -closed, Y 02 -closed and BF3124 (F31A) -open* Fill in a Requester, date, extension and work group Prepare an Attachment 3 with the following information:
* Date Placed: Current date* Clearance Number: 99-1240* SUS Number: 024-03* Svstem/Component:
SBODG Air Compressor 1 (C340A)Have copies of Attachments 4, 5 and 7 Drawing OS-26, Revision 19 Davis-Besse Operations Valve Book Work Order Cover Sheet E-1040A, Electrical Distribution Book, Revision 255 DB-OP-0620 9 , Stator Cooling Water System Operating Procedure, Revision 2, Change 1 JPM A2 Page 2 of 6 GENERAL
 
==REFERENCES:==
 
NG-DB-00250, Safety Tagging, Revision 00 Drawing OS-26, Revision 19 Davis-Besse Operations Valve Book E-1040A, Electrical Distribution Book, Revision 255 DB-OP-0620 9 , Stator Cooling Water System Operating Procedure, Revision 2, Change 1 INITIAL CONDITIONS:
The plant is currently operating at 100W.Stator Cooling Water Pump 2 is in operation.
NOMS is currently out of service and will not be restored for another four hours.Thermography has found a hot spot on the lugs of the motor for Stator Cooling Water Pump 2.The Shift Supervisor has determined that Stator Cooling Water Pump 1 needs to be placed in service to replace Stator Cooling Water Pump 2 as soon as possible.
Stator Cooling Water Pump 1 has a leak on the pump's mechanical seal that must be replaced prior to placing it in service.INITIATING CUES: The Shift Supervisor has directed you to prepare a safety tagout for Stator Cooling Water Pump 1 for replacement of the mechanical seal.(Hand the trainee a prepared copy of Attachment 2 of NG-DB-00250 and Work Order Cover sheet.)
JPM A2 Page 3 of 6 INITIAL CONDITIONS:
The plant is currently operating at 100%.Stator Cooling Water Pump 2 is in operation.
NOMS is currently out of service and will not be restored for another four hours.Thermography has found a hot spot on the lugs of the motor for Stator Cooling Water Pump 2.The Shift be placed possible.seal that Supervisor has determined that Stator Cooling Water Pump 1 needs to in service to replace Stator Cooling Water Pump 2 as soon as Stator Cooling Water Pump 1 has a leak on the pump's mechanical must be replaced prior to placing it in service.INITIATING CUES: The Shift Supervisor has directed you to prepare a safety tagout for Stator Cooling Water Pump 1 for replacement of the mechanical seal.
JPM A2 Page 4 of 6 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate copy of NG-DB-002 5 0, Safety Tagging.STANDARD:
Locate copy of NG-DB-002 5 0, Safety Tagging.COMMENT: Sequence is not required for this JPM.Hand trainee a copy of NG-DB-00250.
CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Review the Clearance Request, Attachment 2..C.STANDARD:
Identify that Y 2 should be Y 3 and BF3124(F31A) should be BE3124(E31A).
COMMENT: The trainee should contact the requester about the errors.CUE: The requester agrees with your changes and asks you to change Clearance Request accordingly.
SAT UNSAT 3. PERFORMANCE STEP: Verify that no active clearance satisfies the boundaries of the Clearance Request.STANDARD:
Check with Shift Supervisor about the active clearance books.COMMENT: Provide cue only if trainee asks about existing active clearances.
CUE: There are no active clearances that support the boundaries of the Clearance Request.SAT UNSAT 4. PERFORMANCE STEP: Verify that no unsigned clearance satisfies the boundaries of the Clearance Request.STANDARD:
Check with Shift Supervisor about clearances that are not signed by the Clearance Authority.
COMMENT: Provide cue only if trainee asks about clearances with no Clearance Authority signature.
CUE: There are no unsigned clearances that support the boundaries of the Clearance Request.SAT UNSAT JPM A2 Page 5 of 6 5. PERFORMANCE STEP: Complete Clearance Cover Sheet, Attachment 4..C.STANDARD: Write in the `Remarks and Instructions" to remove Stator Cooling Water Pump 1 from service using DB-OP-06 2 0 9 , Stator Cooling Water System, Section 4.5 COMMENT: Provide trainee a copy of Attachment
: 4. Provide a copy of the SUS System list and Attachment 3, if requested.
NOTE: This step is NOT critical if vent and drain plug removal is identified on Attachment 7.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Complete Tag Assignment Sheet, Attachment 7..C.STANDARD: Enter the following components and positions:
Y 01, No. 1 SCW Pump Suction Vlv, -Closed.Y 03, No. 1 SCW Pump Discharge Vlv -Closed.BE3124(E31A), Gen Stator Clng Wtr Pmp 1 -Open.Stator Cooling Water Pump 1 -drain plug -removed (tagged or untagged).
Vent plug between SCW Pump 1 and Y 03 -removed (tagged or untagged).
COMMENT: Provide trainee a copy of Attachment 7.NOTE: Critical to identify removal of is not listed on Attachment 4.items is not critical; however, critical.vent and drain plugs if procedure The order of entry of the above proper sequencing of the tags is CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Complete Clearance Holder Sheet, Attachment 5.STANDARD:
Enter the appropriate data.COMMENT: Provide trainee a copy of Attachment 5.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM A2 Page 6 of 6 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ RO [ SRO [ ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date X y ACH 4 A COVER CLEARANCE COVER SHEET SUS NO. I CLEARANCE NO. REV. NO.'_ 97-0/ ? q-,7 qt 0 PAGE I OFZ2_ _ _ _ A T NG-DB-u025u_
EQUIPMENT:, -I- , _- j;- rp t .ArtM4p /REQUESTED BY: R S I c cMcCt .PHONE/PAGER:
SCO REQUEST FOR: DATE: / / SHIFT (M,D,E): DOES THIS CLEARANCE BREACH-A CONTAINMENT PENETRATION?
t ] YES L4 NO OUTAGE CLEARANCE?
[ ] YES WORK TO BE DONE Re 1 7Igac e zqct fn f1f i / S tC'LJ REMARKS AND INSTRUCTIONS AC MeV _- fv sccr c aice 5 rr 410e .-Avt~r f- s-cev4Me As 's, SectC, x ' ., ,5S '- 'f f-~-6-v'of 610-01-06;*0 9{PREPARED BY: DATE: / / TIME: REVIEW BY: DATE: / I TIME: CLEARANCE APPROVED:
DATE: / / TIME: CLEARANCE ISSUED: DATE: / / TIME: PREPARED BY: DATE: f / TIME: REVIEW & APPROVAL BY: DATE: / / TIME: CLEARANCE RELEASED BY: -DATE: / / TIME:-~-Attachment 4 Page I of 1 Aky ATlAC ET 5: CLEARANCE HOLDERSHEEI CTLEARANq(CE HOLD1nR SH ET I SUS NO. CLEARANCE NO. REV. NO.I-l1-01Ht
\aS o NG-DB-00250 PAGE 5 OF, EQUIPMENT:-
WORK DOCUMM WORK DESCRIPTION ACCEPTED BY PHONE/PAGE ACCEPT RELEASED (PRINT) NO. DATE/TIME/SI GMATE/TIME/SI
_ _ _ _ _ _ _ _ < ! Q k _ _ _ _ _ _ _ ___________===_____________I__________
Attachment 5 Page I of 1 AITACHMENT 7: TAG ASSIGNMENT SHEET TAG ASSTGNMNNT SHEET I SUS NO.c7-o /CLEARANCE NO. I REV. NO.i c/-R Y/ I .PAGE J OF (NG-DB-00250 EQUIPMENT:
TAG EQUIPMENT ID ALTERNATE ID FUSE PLACEMENT RESTORATION HQ. EQUIPMENT DESCRIPTION SEQ Initial SEQ Initials pLA PLANT LOCATION NO. NO.REL U Bld Elv Room Verbal Description POSITION 1st 2nd POSITION 1st 2nd-1 3/F3 14i; __&'~AS 5 C/, f,W*Yii/a1o pt 77; h 6/25 -19 CA; jl~ ' Jx __ --{D o, ,__A. I SCAW4- "7 tf/ L VUv g C(cseX 7 h- v i d k .< 5 4J?*I .__7/ I/o' ' I .1 -.-_~~ Sic fiff tSeS Ad, i-s o7 .31s~,.O i ' CZ -'f -, bS -- Z&sect; ~g I IL 7 I _It I Attachment 7 Page I of I FEARMS DAVIS-BESSE PLANT SUB097-01 Work Order 99-003299-000 S Subsystem:
SUB097-01 Asset: SUB097-01 STATOR COOLING SYSTEM Problem Locn: *****_****_***
File no: 4503 Route: 00000 WO Type: Repetitive Action: CORRECTIVE MAINTENANCE Work Class: Shutdown:
N Mat.Acct:
4531.4531.IS.NP13B.DBRX.00000.00 Clearance:
Y Printed: 13-SEP-99 Clearance number: Quality Class: S Tech Spec: N Environmental Qualification:
N Test Requirements:
Y ASME Component:
Lead Craft: INST & TEST Repair Tag number: Train: Permission to Commence Work SS/SM Authorization:
DATE SUPERVISOR DATE Requested by: MECH PLANNER, Phone: 7237 Planner: DAVID TOWNER Phone: 7237 Work
 
== Description:==
 
Replace the mechanical seal on Stator Cooling Water pump 1.Work Order Review Lead Shop Review DATE Special Instructions:
Test Requirements:
Test Test Test Type Function Procedure Craft Signature Date 2 TSC SEE NOTE 1 BELOW OPS Test Requirements Comments: NOTE 1: VERIFY MECHANICAL SEAL DOES NOT LEAK AFTER THE PUMP IS RETURNED TO SERVICE.Page 1 of 5 ATTACHMENT 2: CLEARANC REQUEST CLEARANCE REQUEST EQUIPMENT NAME JOB No.NG-DB-00250 Work Group(s):
.I a8>L yLv I -e.- eLI IACt Or ,,I* Ct nT *Description of Work: R ~c, c e. gtc rcccses so e9X Pt2 7, (coo e ~c~;/9tif /, Reference Drawings Requirements (Include recommended components to be tagged and their position)tbsolated Electrically EIsolated Mechanically 0 Grounded [B-Vented I0-Drained E Brkr Removed 0 System Breach C Other YO I C /o~cf Ig 2 4F.?I 4) -REQUESTER PRINT & SIGN EXT. WORK GROUP.DAT ^/LI 7 1 /iqh OPERATION'S REVIEW NOTES AtaCIchrne 2 Page I of I A LTrACHM ANT 3: CT.ARANC INDEX w nn- n nAf I\Date Clearance SUS SYSTEM/COMPONENT Date Placed Number Number -Noun Name, Equipment ID Number Removed v Sc6 3 ,ert (oi~r eSS~ / (C- 3'C- ),- -.II _I I I i A t i-4 4 I I- I 4 I____ .1. 1 4 1-_ _ _ I I I It I_ _ I _ _ _ 1 _ _ _I -i i i__ 11 __________
__Attachment 3 Page 1 of I AVIS-BESSE ADMINISTRATIVE Safety Tagging ATTACHMENT2:
CLEARANCE REQUBST EQUIPMENT NAME JOB No.CLEARANCE REQUEST NG-DB-00250 Work Group(s): Description of Work: Reference Drawings Requirements (Include recommended components to be tagged and their position)O Isolated Electrically Cl Isolated Mechanically 0 Grounded 0 Vented a Drained 0 Brkr Removed 0 System Breach 0 Other REQUESTER PRINT& SIGN DATE EXT. WORKGROUP OPERATION'S REVIEW NOTES AtLacnmeiin-l 2 Page 1 of I ATA NT4: iCLEARANCROVEKSHEET LRATANCR CoVER qHRET I.FA I SUS NO. l CLEARANCE NO. REV. NO.1 1 mg.- nn- n2 nirn PAGEa OF I C EQUIPMENT:
REQUESTED BY: SECTION: PHONE/PAGER:
REQUEST FOR: DATE: / / SHIFT (MDE): DOES THIS CLEARANCE BREACH A CONTAINMENT PENETRATION? ( l YES [ I NO OUTAGE CLEARANCE?
C I YES WORK TO BE DONE REMARKS AND INSTRUCTIONS PREPARED BY., DATE: / TIME: PLACEMENT REVIEW BY: DATE: TIME: SECTION CLEARANCE APPROVED:
DATE: I / TIME: CLEARANCE ISSUED: DATE: I / TIME:-PREPARED BY: DATE: / / TIME: RESTORATION REVIEW,& APPROVAL BY: DATE: / I TIME: SECTION CERCERELEASED BY: DATE: I I TIME: Attachment 4 Page I of I ED 7575A s, i A1TACT. R- CLEARANCE HOLDER SeT MTRARAh 'PRn R. ET SUS NOl CLEARANCE NO.J.REV.
NO.F NG-DB-002 50._ _ _ _ _ _ _ _ZUiLk'+/-lzw-r WORK DOCUMEM WORK DESCRIPTION ACCEPTED BY PHONE/PAGE ACCEPT RELEASED (PRINT) NO. DATE/TIME/SI GATE/TIME/SI 0 .N Attachment 5 Page 1 of I ATTACHMEW&
6PERSONALREDCL.tNF I"r'DC% %RI A I r'% % r- CA rhA K 2A%MeN rsrn ^~n^ Dot, ^CL---& -d -d NLJOU UJ-V4U V ncv. w Flit%#%iBAL gltU 91ii lA *ti neL.. I VL I WORK DESCRIPTION APPROVED BY.Shon SuDervisor TIME I DATE PREPARED BY- AUTHORIZED BY-rTMF MTVhft, qu wervi4or _ rT MAM PLACEMENT RESTORATION_.
TAG DEVICE IN4D NO, .POSITION SEQ VERIF POSITION SEQ VERIF VERIF BY BY_-=_____-_-
TAGS REMOVED AND'DESTROYED Shop Supervisor TIME IDATE Attachment 6 Page I of 1 I t ATACHMENT 7- TAG ASSIGNMENTSHEI
'VAO AqqT(-,NMFWNTP qH.ET I NG-DB-00250 I SUS NO. CLEARANCE NO. REV. NO.-I PAGE OF EQUIPMENT:
TAG EQUIPMENT ID ALTERNATE ID FUSE- PLACEMN _ RESTORAION 1HJgj EQUIPMENT DESCRIPTION SEQ Inta QIiil pLA PLANT LOCATIONNOIntasnial RE'U Bld Elv Room Verbal Description NO. TONls NO.STINls n Attachment 7 Page I of I ATT-11ACHMF8:
CLE-ARANCEREWrSIONEEQYEST NG-DB-00250 CLEARANCE REVISION REQUEST CLEARANCE NUMBER SUS NUMBER REQUESTED BY EXT REASON-.OR CHANGE TAG # COMPONENT POSITID TAG COM OVE R SOSITAL TAGCOTPOSITION SPECIAL REQUIREMENTS CHANGE AGREEMENT COORDINATION Component positioning relating to Changes to Clearances will be performed with direct reference to the Tag Assignment Sheet, not this Change to Clearance form.PRINT NAME & EXT I CTIPNAhrMWP' I 1 We ?kWTMMD ad' lI- I n%% l I CHANGE DISAPPROVED SS TIME DATE REASON FOR DISAPPROVAL A "evvfQ Pagel of2
-: e e AIT1ACMNT 8- CT-EARANCP.
REVISION REQPSPT (Continued)
NG-DB-00250 CLEARANCE REVISION REQUEST CONTINUATION CLEARANCE NUMBER SUS NUMBER __-.EQUSTED Mu tr EUESTE TAG
* COMPONENT POSITION TAG # COMPONENT POSITION CHANGE AGREEMENT COORDINATION Component positioning relating to Changes to Clearances will be performed with direct reference to the Tag Assignment Sheet, not this Change to Clearance ferm.PRINT NAME & EXT SIGNATURE WO NUMBER(s)
DATE TIME J.. I _ I I -Attachment 8 Page 2 of 2 AAlCHMENTI9:
CLEARANCEREVISION l SS No. CLEARANCE NO. I tEV. tro. lOEQIPMENT WD ALTERNATE 10 FUSE PLACEENT RETURl TO ItORYAL PATLCTO:INITIALS IIIL U Bid Elv No= Verbat Description SE SE____.. ____. __.Nt. NO. POSITION let .Ps_ .III////I/i
,,I//I///11J lU/IHI//11 Il/I l/Il./ / /I l PRE P ARE B/YIDATE///
I/Il I/I/E.II. III I//IIIIIII/
Il/I I/Ill.' /1/ Il/I/Im Ill/I Ill/IX/II IIIIIAttac//h 9/Il /Il.__ _ II I I//t///xa I//of I/I III Il/Il//u//
iiiii liii,_ _ /1 ihiiliiiltq Il//I Il/I.~Il .iIIIIII/B/i//
I/Ill t//Il_ _ I,, Iltllll//,S I/Ill Il/I/Ill Ill/llil/li Il//I Ill/I.Ill lll/l///i///
I/Ill I/Ill_ _ ._ _I/I lll//I/lU/
I/Il/ 11/11./1/ ll/lii///l/
Ill//I l/Il..I// l/I///I////
Il/Il/ I/Ill______ I/I I//Ill////I I//I/ Il//Il ../11 ////l////X//
l//I/ I //Il.~l I/////I//Il//
Il/I/ I//Il_ _ Ill /h/////j///
1/Ill Il//I I I ; Il. I/I////I///It I/Ill Il/I.~~, ///I/u///i///
Ill/ I /Ill.' .// / Page/ 1 ofttahmn 9//
ATTACHMENT 10: TEMPORARY Lffi NG-DB-00250 TEMPORARY LIFT----CLEARANCE NO _ _ SUS NO. EST DUI REQUESTED BY REASON FOR TEMPORARY LIFT RATION IHRS EXT I.COMPONEMTS T.TETRr TAG #COMPONENT l l7 I.-l-l l7 CPF=PT1AT-10W;%TTTl0=X1;1MQ:
oJrce; l-TEMPORARY LIFT AGREEMENT COORDINATION Temporary lifting of. Red Tags is an unconditional release of equipment.
Positions may be changed from the abovj stated positions without further approval from the c earance olders.PRINT NAME & EXT SIGNATURE I WO NflMRER(s I DATE I TIME I:A_: ' .-.\ , ' =I-TEMP LIFT REVIEWEr TIME/DATE LIFT APPROVED/DISAPPROVED TIME/DATE ASSIST SS SS _REASON FOR DISAPPROVAL TEMPORARY LIFT PERFORMED, REQUESTER NOTIFIED SS TIME DATE TEMPORARY LIFT RESTORED, ALL CLEARANCE HOLDERS NOTIFIED SS TIME DATE Attachment 10 Page lofI AIACHMElRNTI I e:TEMPOPLARY Lr CONTINUMJ NG-DB-00250
.TEMPORARY LIFT CONTINUATION CLEARANCE NUMBER SUS NUMBER COMPONENTS LIFTED RESTORATION IND DESIRED S VERIF TAGGED SQVERIF VERII TAG 1 COMPONENT POSITION SEQ BYL POSITION SEQ By TEMPORARY LIFT AGREEMENT COORDINATION Temporary lifting of Red Tags is an unconditional release of equipment.
Positions may be changed from the above stated positions without further approval from the clearance holders.PRINT NAME & EXT SIGNATURE WO NUMBER(S)
DATE TIME.~ -=Attachment I1 Page I of I ATTACHMENT 12- SAFETY TAGGING MONTHELY REVIEW NG-DB-00250 REVIEWED)
BY ..DATE REVIEWED BY DATEI..I.- I.-.I= _____I i ii .I 4-iI*fI* I.I I~Attachment 12 Page 1 of I ATEACHMENT 13: SAFETY TAGGING AUDIT NG-DB-00250 Date: Department Issued To: Clearance Index Number: Clearance Assigned To: -Date Clearance Placed: System/Component:
SUS Number: MWO (S) _The following shall be answered by the clearance holder(s).
YES NO 1. Is clearance still required'
-DJ If YES, provide justification 4i e-o qee con- Signature Date The following shall be verified by an operator during the annual audit 2. Are tags still attached?03 0 0 3. Are tags legible-p O List discrepancies in the Comments section.Missing tags shall be reported to the SS, who shall have the tags replaced immediately.
Tags which are illegible shall be prior to completion of the audit.missing replaced Date Signature The audit is completed, discrepancies identified and corrected.
Shift Supervisor Date Attachment 13 Page I of I A1TACBMRNT 14- FLOWCHART I-ROCEDURE NUMBER J 1G-DB-00250 UZ ...Attachment 14 Page 1 of I END DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: A3 Rev. 00 Page 1 of 8 TASK NO.: 000-058-05-0100 TASK DESCRIPTION:
Check Out a Radiation Detector in the RRA K/A
 
==REFERENCE:==
 
GEN-2.3 .5 APPLICABLE METHOD OF TESTING: Actual performance In-plant TIME FOR COMPLETION:
APPLICABILITY:
[XI RO[X] SRO TASK STANDARDS:
: 1. Ensure the portable 2. Verify the portable 3. Ensure the portable a source check.radiation detector is within the Calibration due date.radiation detector is functional.
radiation detector has been source checked or perform REOUIRED MATERIALS:
Radiation Detector Check Source GENERAL
 
==REFERENCES:==
 
DB-HP-01103, Use of Portable Radiation, Contamination and Airborne Survey Equipment, Revision 01, Change 2 DB-HP-00010, Radiation Measuring and Test Equipment Calibration and Control Program, Revision 03, Change 4 INITIAL CONDITIONS:
A large break LOCA has occurred.LPI Pump 2 failed to start.The motor outboard bearing temperature on LPI pump 1 is slowly increasing.
INITIATING CUES: The Shift Supervisor has directed you to inspect the motor on LPI Pump 1 for a potential cause.RP coverage is not available and you are required to obtain a portable radiation detector prior to entering RRA.
JPM A3 Page 2 of 8 INITIAL CONDITIONS:
A large break LOCA has occurred.LPI Pump 2 failed to start.The motor outboard bearing temperature on LPI Pump 1 is slowly increasing.
INITIATING CUES: The Shift Supervisor has directed you to inspect the motor on LPI Pump 1 for a potential cause.RP coverage is not available and you are required to obtain a portable radiation detector prior to entering RRA.
JPM A3 Page 3 of 8 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate a copy of DB-HP-01103, Use of Portable Radiation, Contamination and Airborne Survey Equipment.
STANDARD:
Obtain a copy of DB-HP-01103.
COMMENT: Trainee may elect to use his memory to perform this task.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Obtain a Portable Radiation Detector..C.STANDARD:
Obtain a Bicron RSO-5 or an Eberline R02 at the entrance to the RRA.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Ensure instrument is not past its calibration due date.STANDARD:
Verify the date on the "Calibration" sticker has not been exceeded.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Inspect for physical damage.STANDARD:
Physically inspect the instrument for any damage.CUE: None.SAT UNSAT JPM A3 Page 4 of 8 5. PERFORMANCE STEP: Ensure the mechanical zero is correct.STANDARD:
Verify that the instrument's output meter reads zero with the instrument off.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Turn on the instrument and verify the electronic zero is correct.STANDARD:
Turn on the instrument and verify that it is electronically zeroed.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Perform a battery check..C.STANDARD:
Ensure the instrument indicates the battery is good.CUE: Meter indicates zero.SAT UNSAT 8. PERFORMANCE STEP: Obtain a replacement Portable Radiation Detector..C.STANDARD:
Obtain another Bicron RSO-5 or an Eberline R02 at the entrance to the RRA.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Ensure instrument is not past its calibration due date.STANDARD:
Verify the date on the "Calibration" sticker has not been exceeded.CUE: None.SAT UNSAT JPM A3 Page 5 of 8 10. PERFORMANCE STEP: Inspect for physical damage.STANDARD:
Physically inspect the instrument for any damage.CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Ensure the mechanical zero is correct.STANDARD:
Verify that the instrument's output meter reads zero with the instrument off.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Turn on the instrument and verify the electronic zero is correct.STANDARD:
Turn on the instrument and verify that it is electronically zeroed.CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Perform a battery check..C.STANDARD:
Ensure the instrument indicates the battery is good.CUE: None.SAT UNSAT Page 6 of 8 JPM A3 14. PERFORMANCE STEP:.C.Ensure the completion of, or perform a source check on the instrument.
STANDARD:
Verify the instrument's response is within + 20% of source's value.CUE: Daily source check sticker has not been initialed for today's date.(If trainee attempts to get another replacement meter) No additional hand-held radiation detectors are available.
SAT UNSAT 15. PERFORMANCE STEP: Sign out the instrument.
STANDARD: Fill out the Instrument Use/Response Log, Attachment 7 of DB-HP-00010, Radiation Measuring and Test Equipment Calibration and Control Program.CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Survey for radiation levels while enroute to ECCS.C. Room 2.STANDARD: Frequently check hand-held radiation detector indication while travelling through the Auxiliary Building.
Sweeps area in front of and to both sides of his location with the hand-held radiation detector.COMMENT: Depending on the scale selected by the trainee, the cue may need to be modified to indicate the meter is reading full scale.CUE: (Outside door 105 if trainee is monitoring hand-held radiation detector)
Radiation detector indicates 25 Rem/hr.SAT UNSAT JPM A3 Page 7 of 8 17. PERFORMANCE STEP: Leave the area and notify Shift Supervisor.
.C.STANDARD:
Go to a safe dosage area and call the Shift Supervisor.
COMMENT: As the trainee leaves the area provide decreasing radiation level cues.Depending on the scale selected by the trainee, the cue may need to be modified to indicate the meter is reading zero.CUE: (If trainee is monitoring hand-held radiation detector)
Radiation detector indicates 100 mRem/hr.Shift Supervisor directs you to standby.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM A3 Page 8 of 8 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ RO [ SRO [ ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ I SATISFACTORY
[ ] UNSATISFACTORY NOTE: An 'Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: A4 Rev. 00 Page 1 of 5 TASK NO.: 000-080-05-0100 TASK DESCRIPTION:
Given Dose Assessment Data, Determine the Appropriate Protective Action Recommendations K/A
 
==REFERENCE:==
 
GEN-2.4.3 9 , GEN-2.4.44 APPLICABLE METHOD OF TESTING: Actual performance Classroom or simulator TIME FOR COMPLETION:
10 minutes APPLICABILITY:
[XI RO [XI SRO TASK STANDARDS:
Determine protective action recommendations based on given dose calculations.
REqUIRED MATERIALS:
RA-EP-02 2 4 5, Protective Action Guidelines, Revision 0, Change 1.Fill out an Off-site Dose Assessment Nomogram with following information:
* Stability Class = E* Wind Speed 1 mph* Flow Rate = 146 KCFM* Radiation Monitor Reading = 0.1 gCi/cc* 0.75 mile = 5.5 rem/hr.* 2 miles = 1.1 rem/hr.* 5 miles = 0.37 rem/hr.* 10 miles = 0.14 rem/hr.GENERAL
 
==REFERENCES:==
 
RA-EP-02245, Protective Action Guidelines, Revision 00, Change 1.INITIAL CONDITIONS:
A large break LOCA is in progress with no indications of core melt.Containment has been breached and a release from the station vent is in progress.DADS is out of service.The current wind direction is 3000.INITIATING CUES: The Shift Supervisor has determined the off-site dose rate using a nomogram.The Shift Supervisor directs you to determine the off-site protective action recommendations using the TEDE values only.(Hand the examinee the nomogram.)
JPM A4 Page 2 of 5 INITIAL CONDITIONS:
A large break LOCA is in progress with no indications of core melt.Containment has been breached and a release from the station vent is in progress.DADS is out of service.The current wind direction is 3000.INITIATING CUES: The Shift Supervisor has determined the off-site dose rate using a nomogram.The Shift Supervisor directs you to determine the off-site protective action recommendations using the TEDE values only.
JPM A4 Page 3 of 5 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C".standards for this item constitutes unless denoted in the "Comments".
Failure to meet any one of these failure. Sequence is assumed START TIME: l 1. PERFORMANCE STEP: Locate a copy of RA-EP-02245, Protective Action.C........
Guidelines and go to Attachment 2.STANDARD:
Locate Attachment 2 of RA-EP-02245.
COMMENT: Hand the trainee a copy of RA-EP-02245.
CUE: None.SAT UNSAT 2. PERFORMANCE STEP:.C.Determine the affected subareas and enter the information in Column A.STANDARD: Using the wind direction and Attachment 3, determine the affected subareas.
For distance 0 -2 miles Subareas 1 and 12, distance 2 -5 miles Subareas 2 and 6, and 5 -10 miles Subareas 7, 8 and 9. Circle the affected subareas in column.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Enter the TEDE dose rate from the Off-site Dose.C........
Assessment Nomogram into Column B.STANDARD:
Write the correct value into Column B.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Enter the expected release duration into Column C..C.STANDARD:
Enter 2 hrs. into Column C.CUE: None.SAT UNSAT JPM A4 Page 4 of 5 5. PERFORMANCE STEP: Calculate the doses at the various distances and enter.C. the values into Column D.STANDARD:
Enter 11 rem for 0.75 mile, 2.2 rem for 2 miles and 0.74 rem for 5 miles.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Identify the appropriate protective action.C. recommendation for the various distances.
STANDARD:
Compare Column D to Column E and circle in Column F,'evacuate' for 0.75 mile, 'evacuate' for 2 miles and 'No Protective Action' for 5 miles.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM A4 Page 5 of 5 Operator SSN License: VERIFICATION OF COMPLETION Evaluator Date[ ] RO [ ] SRO [ ] ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date
/<~ef PROTECTIVE ACTION GUIDELINES 11-"AA-EP-02245 Revision 00 C-1 ATTACHMENT 2: PROTECTIVE ACTION RECOMMENDATIONS BY AFFECTED SUBAREA (cont'd)------- -TAJBLE 1: PROTECTIVE ACTIONS AND AFFECTED SUBAREAS Distance A B C D E F.From Affected Doserate Release Dose Limit Protective Action Plant Subareas (REM/hr) Duration (hr) (REM) (REM) R e mendation (0-2 miles) QEvacuate TEDE r I ,1 No: No Action 0.75 (i 'J' -I (Evacuate if in General Emergency) mile Yes: Evacuate Thyroid CDE 2)>5 No: No Action (Evacuate if in General._ .Emergency)
(2-5 miles) Evacuate TEDE _______I II> 1 No: No Action 2 (2) 1 (Evacuate if in General Emergency) mile (9Yes: Evacuate Thyroid 10 CDE (12) > 5 No: No Action (Evacuate if in General Emergency)
(5-10 miles) Yes: Evacuate 3 TEDE 54 > (9.37 No Protective 4 ( ,71 Action mile Yes: Evacuate (S Thyroid C1 CDE (12)>5 No: No Protective 11 Action Performed by: Signature Date ATTACHMENT 2 Page 2 of 2 FINAL AS-ADMINISTERED WALKTHROUGH JPMS FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13,1999
'T0 5+ rR F We& 4L ES-301 Control Room Systems and Facility Walk-Through Test Outline Form ES-301-2 Facility:
Davis-Besse Nuclear Power Station Date of Examination:
9L13/1999 Exam Level (circle one): RO / SRO(I) I SRO(U) Operating Test No.: (Post NRC Review)B.1 Control Room Systems System / JPM Title Type Safety'Q Code* Function a. ECCS I Return Decay Heat Train/to Low Pressure D,S,L 2 Injection Mode b. ECCS (LB LOCA) / Initiate Long Term Boron Dilution D,A,S 3 Flowpath c. RHR I Start High Pressure Injection Pump Upon Loss of a M,A,S,L 4p Decay Heat Pump d. CSS / Recover from Inadvertent Safeguards Actuation N,S 5 Levels 1-4 e. NNI / Restore ICS to Full Automatic Control N,S 7 f. IAS I Loss of Instrument Air Actions From the Control D,S 8 Room g. WGDS / Purge Containment in Mode 5 D,A,S,L 9 B.2 Facility Walk-Through
: a. SWS (loss of NSW) I Use Circulating Water to Supply D,L 4s Service Water Primary Loads b. AC Electrical
/ Local Transfer of 13.8 KV Bus A Source N,A,L 6 c. CRD (Dropped Control Rod) / Clear Asymmetric Fault D,R 1* Type Codes: (D)irect from bank, (M)odified from bank, (N)ew, (A)lternate path, (C)ontrol room, (S)imulator, (L)ow-Power, (R)CA JPM No. 93B Page 8 of 15 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Return Decay Heat Train 2 to LPI Mode INITIAL CONDITION:
Mode 4, 270 0 F, 250 psig, Maneuver here from 273 0 F Training IC #36. Only do switch check for front panels. Skip keys to save time!ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
* Place Decay Heat Loop 2 in decay heat lineup DH 1518 OPEN, DH 2734 CLOSED, DH 14A, 13A at 20% demand, CC 1469 OPEN.* Place OPEN placard on DH 1518.* Place CLOSED placard on DH 2734 and DH 63.* Place Ops Info tags on DH 1518, DH 2734, and DH 63 stating "Breaker open per DB-OP-06012".
MALFUNCTIONS/FAILURE TO INSERT: None.ACTION/CUES:
: 1. ACTION: CLOSE DH 60, DH Pump 1-2 Discharge Sample Isolation Valve.CUE: DH 60 is CLOSED.2. ACTION: Verify DH 26, DH Pump 1-2 Minimum Cooldown Isolation Valve.CUE: DH 26 is CLOSED.3. ACTION: Remove the CLOSE power fuses from AD112 for DH Pump 1-2.CUE: The CLOSE power fuses have been removed from AD112, DH Pump 1-2 breaker.4. ACTION: Close BF 1129 and BF 1134 on FllC and BF 1195 (FliE).CUE: BF 1129, BF 1134, and BF 1195 have been closed. (Give cue for each breaker as called for.)5. CUE: Attachment 25 has been completed.
: 6. ACTION: Install the CLOSE power fuses in AD112 for DH Pump 1-2.CUE: The CLOSE power fuses have been installed in AD112, DH Pump 1-2 breaker.7. ACTION: Verify DH 14A OPEN locally.CUE: DH 14A is OPEN to the hard stop.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 93B Rev. 04 Page 9 of 15 TASK NO.: 005-009-01-0100 TASK DESCRIPTION:
Return Decay Heat Train 2 to LPI Mode K/A
 
==REFERENCE:==
 
005-000-A4.01 (3.6/3.4);
005-000-A4.02 (3.4/3.1)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
21 minutes APPLICABILITY:
[XJ RO[X] SRO TASK STANDARDS:
Lineup Decay Heat Loop 2 to the LPI mode.REOUIRED MATERIALS:
DB-OP-06012, Decay Heat and Procedure, Revision 04 Low Pressure Injection System Operating GENERAL
 
==REFERENCES:==
 
DB-OP-06012, Decay Heat and Low Pressure Injection Procedure, Revision 04 System Operating INITIAL CONDITIONS:
The plant is in Mode 4 with a plant heatup in progress.RCS temperature is 270 0 F.RCS pressure is 250 psig.RCPs 2-1 and 2-2 are running.Decay Heat Loop 1 is aligned for LPI mode.Decay Heat Pump 1-2 has just been stopped.INITIATING CUES: The Shift Supervisor directs you to line up Train 2 of Decay Heat to the LPI mode using DB-OP-06012, Decay Heat and Low Pressure Injection System Operating Procedure.
You have permission to operate all locked valves required for this procedure and the Locked Valve Log entries have been made.(Hand DB-OP-06012 to examinee.)
JPM No. 93B Page 10 of 15 INITIAL CONDITIONS:
The plant is in Mode 4 with a plant heatup RCS temperature is 270 0 F.RCS pressure is 250 psig.RCPs 2-1 and 2-2 are running.Decay Heat Loop 1 is aligned for LPI mode.Decay Heat Pump 1-2 has just been stopped.in progress.INITIATING CUES: The Shift Supervisor directs you to line up Train 2 of Decay Heat to the LPI mode using DB-OP-06012, Decay Heat and Low Pressure Injection System Operating Procedure.
You have permission to operate all locked valves required for this procedure and the Locked Valve Log entries have been made.
Page 11 of 15 JPM No. 93B PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure section.STANDARD:
Locates Section 3.13 as the correct section.CUE: All prerequisites are complete.SAT UNSAT 2. PERFORMANCE STEP: Verify DH Pump 2 is stopped using HIS DH 6A.STANDARD:
Verify Green light is lit on HIS DH 6A.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Verify DH Loop is not aligned to MU and Purfication or SFP Purification.
STANDARD:
Verify Section 4.13 and 4.15 are complete.CUE: Sections 4.13 and 4.15 of DB-OP-06012 were completed on the previous shift.SAT UNSAT 4. PERFORMANCE STEP: Close CC 1469, DH Cooler 1-2 CC outlet.STANDARD:
Depress CLOSE pushbutton on HIS 1469.COMMENT: Trainee may also elect to STOP CCW Pump 2 due to low flow caused by CLOSING CC 1469.CUE: None.SAT UNSAT JPM No. 93B Page 12 of 15 5. PERFORMANCE STEP: Verify DH 830/DH 831, DH Cooler 1-1/1-2 cross connects are closed.STANDARD:
Verify Green light LIT on HIS 830/DH 831.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Verify closed DH 2735 & DH 2736 DH aux. spray valves.STANDARD:
Verify Green light LIT on HIS 2735 and HIS 2736.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Verify DH 1A, DH Pump 1-2 discharge to RCS is open with control power removed.STANDARD:
Verify Red light on HIS DH1A is LIT and Blue "CTRL PWR OFF" light is Lit on HIS DH1A-2.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Verify DH 7A, BWST Line 2 isolation is open.STANDARD:
Verify Red light LIT on HIS DH7A.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Remove close power fuses for AD112.STANDARD:
Dispatch an Equipment Operator to remove the "CLOSE" power fuses from AD112 for DH Pump 1-2.CUE: None.SAT UNSAT JPM No. 93B Page 13 of 15 10. PERFORMANCE STEP: Close Breaker BF1129 (FliC)..C.STANDARD:
Dispatch an EO to close Breakers BF 1129 (DH 1518).CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Close DH 1518, DH Pump 1-2 suction from RCS..C.STANDARD:
Depress CLOSE HIS 1518.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Close Breaker BF1195 (FllE).STANDARD:
Dispatch an EO to close BF1195 (FllE).CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Verify DH 63, DHR CLR 2 outlet to HPI Pump 2 suction, is CLOSED.STANDARD:
Verify Green light is lit on DH 63.CUE: None.SAT UNSAT 14. PERFORMANCE STEP: Dispatch an EO to check pressure on the suction line of DH Pump 1-2.STANDARD:
Dispatch an EO to check pressure on DH Pump 1-2 suction line, per Step 3.13.21.CUE: DH Pump 1-2 suction pressure is 32 psig.SAT UNSAT Page 14 of 15 JPM No. 93B 15. PERFORMANCE STEP: Close Breaker BF1134 (FliC)15. PERFORMANCE STEP: Close Breaker BF1134 (Fl1C)-.C.STANDARD:
Dispatch an EO to close Breaker BF1134 (FliC)CUE: None.SAT UNSAT 16. PERFORMANCE STEP:.C.Open DH 2734, DH Pump 1-2 suction from BWST or emerg.sump.STANDARD:
Depress OPEN on HIS 2734.CUE: None.SAT UNSAT 17. PERFORMANCE STEP: Install close power fuses.C.STANDARD:
Dispatch an Equipment Operator to fuses in AD112 for DH Pump 1-2.in AD112.install the "CLOSE" power COMMENT: Only critical if the fuses were removed previously.
CUE: None.SAT UNSAT 18. PERFORMANCE STEP: Notify the Shift Supervisor that DH Loop 2 is in standby LPI mode and to perform an operability evaluation.
STANDARD: Communicate with the Shift Supervisor to inform him of the DH/LPI System status and request operability evaluation.
CUE: The Shift Supervisor acknowledges DH Loop 2 in LPI mode. LPI Loop 2 has been determined to be operable.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 93B Page 15 of 15 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date
-JPM No. 02C Page 12 of 17 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Initiate a Long Term Boron Dilution Flowpath INITIAL CONDITION:
100 percent power anytime in life. Insert a large break LOCA, deposit TVHH0101 to 1.0, then allow it to run until RCS pressure is < 200 psig.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
Transfer LPI suction to CTMT Emergency Sump.Close breakers for DH11 (TCB11152) and DH12 (TCB11252).
MALFUNCTIONS/FAILURE TO INSERT: Close DHlO and DH26 ACTION/CUES:
: 1. Step 8: Flow on FI 4999 is 50 gpm.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 02C Rev. 07 Page 13 of 17 TASK NO.: 000-058-05-0100 TASK DESCRIPTION:
Initiate a Long Term Boron Dilution Flowpath K/A
 
==REFERENCE:==
 
006-XXX, A4.02 4.0/3.8, GEN-XXX-2.1.30, 3.9/3.4 APPLICABLE METHOD OF TESTING: Actual performance Simulator Control Room Alternate path TIME FOR COMPLETION:
APPLICABILITY:
[XI RO 10 minutes[XI SRO TASK STANDARDS:
Establish an auxiliary flowpath through the core by creating another discharge path through DH 2735, 2736.REOUIRED MATERIALS:
DB-OP-02000, Rev. 05, RPS, SFAS, SFRCS or SG Tube Rupture GENERAL
 
==REFERENCES:==
 
DB-OP-02000, Rev. 05, RPS, SFAS, SFRCS or SG Tube Rupture INITIAL CONDITIONS:
The plant has experienced a large break LOCA. Suction for the LPI pumps has been swapped to the emergency sump. Both LPI pumps are in service. The breakers for DH11 and DH12 are closed.INITIATING CUES: The Shift Supervisor has obtained the TSC concurrance and directs you to line up for long term boron dilution using the decay heat drop line (preferred method) in accordance with DB-OP-02000, Step 10.14.
JPM No. 02C Page 14 of 17 INITIAL CONDITIONS:
The plant has experienced a large break LOCA. Suction for the LPI pumps has been swapped to the emergency sump. Both LPI pumps are in service. The breakers for DH11 and DH12 are closed.INITIATING CUES: The Shift Supervisor has obtained the TSC concurrance and directs you to line up for long term boron dilution using the decay heat drop line (preferred method) in accordance with DB-OP-02000, step 10.14.
JPM No. 02C Page 15 of 17 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is NOT required unless denoted in the "Comments".
START TIME: I 1. PERFORMANCE STEP: Locate the correct procedure section.STANDARD:
Identifies DB-OP-02000, RPS, SFAS, SFRCS or-SG Tube Rupture, Section 10 as correct section.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Open DH 11, RCS to DH System Iso. Valve.STANDARD:
Apply control power by pressing ON at HIS 11A.Press OPEN on HIS 11.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Open DH 12, RCS to DH System Iso. Valve.STANDARD:
Apply control power by pressing ON at HIS 12A.Press OPEN on HIS 12.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Verify a minimum flow of 40 gpm.STANDARD:
Visual check via FI 4908 and FI 4909.CUE: (If asked), The Shift Supervisor directs you to continue with the procedure while he looks into the reason for the lack of flow.SAT UNSAT 5. PERFORMANCE STEP: Close DH-ll and DH-12..C.STANDARD:
Press CLOSE on HIS DH 11 and HIS DH 12.CUE: None.SAT UNSAT JPM No. 02C Page 16 of 17 6. PERFORMANCE STEP: Close RC-10, Pzr. Spray Iso. Valve.STANDARD:
Verify CLOSE on HIS RC 10.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Open DH-2736, DH Aux. Spray Throttle Valve and.C. DH-2735, DH Aux. Spray Stop Valve.STANDARD:
Press OPEN on HIS 2735 and HIS 2736.NOTE: DH-2736 is a throttle valve. The OPEN button will have to be held until the valve is fully open.CUE: (If asked) You have permission for locked valves.SAT UNSAT 8. PERFORMANCE STEP: Verify minimum flow of 42 gpm.STANDARD:
Direct EO to report flow as read on FI 4999.COMMENT: Have Trainee utilize EO for this step.CUE: Flow on F1 4999 is 50 gpm.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 02 Page 17 of 17 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date JPM No. 91C Page 19 of 26 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Start High Pressure Injection Pump upon a Loss of One Decay Heat Pump INITIAL CONDITION:
RCS Drained to 80 inches, DH Loop 2 in Service ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
0 a 0 0 0 0 0 Remove breaker open placards from DH7A and DH7B.SPDS Decay Heat Removal Screen is not working.Verify DH14A, DH14B, DH13A, and DH13B are closed.Hang Red Tags on HPI Pumps 1 & 2 control switches.Place Ops Info tags on DH 1517, DH 1518, DH 63, DH 64, DH 2733, and DH 2734 stating "breaker open per DB-OP-06012".
Place OPEN placards on DH 1517 and DH 1518.Place CLOSED placards on DH 63, DH 64, DH 2733, and DH 2734.MALFUNCTIONS/FAILURE TO INSERT: Insert malfunction to fail Decay Heat Pump 2's breaker open (IMF BDP2C).Insert malfunction to fail Decay Heat Pump l's breaker open (IMF BDPlC).ACTION/CUES:
NOTE: Use proper three-part communication for any necessary cues.1. Step 1: (if sent) Breaker AD112 indicates 50/51 phases A and C relays tripped.2. Step 1: (if sent) DH Pump 2 shows no abnormal indications.
: 3. Step 12: Breaker BE 1157-A on EllA for DH7B has been closed. (IRF BD7B)4. Step 13: All tags have been removed from breaker AC111. Breaker AC111 has been racked in (IRF BFP1A OPERATE).
Breaker AC111 close power fuses have been installed (IRF BFP1C FALSE).
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO. 91C Rev. 00 Page 20 of 26 TASK NO. 005-012-04-0100 TASK DESCRIPTION:
Start High Pressure Injection Pump upon a Loss of One Decay Heat Pump K/A
 
==REFERENCE:==
 
GEN-XXX-2.4.4 (4.0/4.3), 025-XXX-AK3.01 (3.1/3.4)APPLICABLE METHOD OF TESTING: Simulate performance Simulator Alternate procedure TIME FOR COMPLETION:
20 minutes APPLICABILITY:
[X] RO [XI SRO TASK STANDARDS:
Start High Pressure Injection Pump 1 or 2 and establish flow to the RCS.REQUIRED MATERIALS:
DB-OP-02527, Loss of Decay Heat Removal, Revision 02 GENERAL
 
==REFERENCES:==
 
DB-OP-02527, Loss of Decay Heat Removal, Revision 02 INITIAL CONDITIONS:
The plant has been in Mode 5 for 25 days.RCS temperature is 130 0 F.RCS level is 80 inches on LI 10577A and B, RCS level indication, for maintenance activities.
Decay Heat Train 2 is in service.Decay Heat Train 1 is in standby.No RCS boron dilution is in progress.CTMT has been evacuated, CTMT closure has been established.
The SPDS Decay Heat Removal Screen is not functioning.
INITIATING CUES: Decay Heat Pump 2 has tripped on overcurrent.
The Shift Supervisor directs you to start Decay Heat Pump 1 in the decay heat mode using DB-OP-02527.
You have permission to operate any locked valves required.Desired decay heat flow is 1500 gpm.(Hand a copy of DB-OP-02527 to the examinee.)
JPM No. 91C Page 21 of 26 INITIAL CONDITIONS:
The plant has been in Mode 5 for 25 days.RCS temperature is 130 0 F.RCS level is 80 inches on LI 10577A and B, RCS level indication, for maintenance activities.
Decay Heat Train 2 is in service.Decay Heat Train 1 is in standby.No RCS boron dilution is in progress.CTMT has been evacuated, CTMT closure has been established.
The SPDS Decay Heat Removal Screen is not functioning.
INITIATING CUES: Decay Heat Pump 2 has tripped on overcurrent.
The Shift Supervisor directs you to start Decay Heat Pump 1 in the decay heat mode using DB-OP-02527.
You have permission to operate any locked valves required.Desired decay heat flow is 1500 gpm.
JPM No. 91C Page 22 of 26 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure attachment.
STANDARD:
Identify Attachment 3, as the correct procedure attachment.
COMMENT: Examinee will most likely route through Section 4.1 of the procedure to Step 4.1.14, which sends him to Attachment 3.Repeat initiating cues as necessary.
Use proper three-part communication for cues.CUE: (If asked) No signs of pump cavitation existed before the pump tripped.SAT UNSAT 2. PERFORMANCE STEP: Close DH 14B.STANDARD:
Depress auto on HIS DH 14B and verify zero demand is indicated on HIC DH14B and/or Green light comes ON.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Close DH 13B.STANDARD:
Depress auto on HIS DH 13B and verify zero demand is indicated on HIC DH1B and/or Green light is ON.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Verify DH 1517 is open.STANDARD:
Observe OPEN placard and Ops Info tag stating breaker is open.CUE: None.SAT UNSAT JPM No. 91C Page 23 of 26 5. PERFORMANCE STEP: Verify open DH 11 and DH 12 or DH 21 and DH 23.STANDARD:
Visual verification of Red light on HIS DH11 and HIS DH12.COMMENT: Use proper three-part communication for cues.CUE: DH 21 and DH 23 are not to be used per SS discretion.
SAT UNSAT 6. PERFORMANCE STEP: Verify CCW and SW cooling is available.
STANDARD:
Verify CCW Pump 1 and SW Pump 1 are running and CC 1467 Red indicating light is LIT.COMMENT: May also check SW36 open by placard and/or SW1424 is open or throttled.
CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Verify DH 1B is open.STANDARD:
Visual verification of Red light is LIT on HIS DH1B.COMMENT: Only critical if DH 1B is closed.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Start DH Pump 1 using HIS DH 6B..C.STANDARD:
Recognize DH Pump 1 does not start.COMMENT: Use proper three-part communication for cues.CUE: (If asked) The Shift Supervisor directs you to continue in the Loss of Decay Heat Removal procedure while he investigates the failure of DH Pump 1.SAT UNSAT 9. PERFORMANCE STEP: Determine if either OTSG is functional.
STANDARD:
Determine if RCS is intact.CUE: (If asked) OTSGs are not available.
SAT UNSAT JPM No. 91C Page 24 of 26 10. PERFORMANCE STEP: Establish a feed flowpath..C.STANDARD:
Determine that an HPI Pump is the available feed flowpath.COMMENT: Use proper three-part communication for cues.CUE: (If asked) The Shift Supervisor directs you to establish a feed flowpath using HPI Pump 1.SAT UNSAT 11. PERFORMANCE STEP: Locate the correct procedure attachment.
STANDARD:
Identify Attachment 5, as the correct procedure attachment.
COMMENT: Use proper three-part communication for cues.CUE: (If asked) The Shift Supervisor has verified the System Status File and Safety Tagging file for HPI show the system valve lineup is complete for Mode 3 entry.SAT UNSAT 12. PERFORMANCE STEP: Establish a flowpath from the BWST through the HPI Pump into the RCS.STANDARD:
Refer to Attachment 10 for flowpaths available.
COMMENT: Examinee may refer to OS 003 and OS 004 or Attachment 10.Examinee may also direct an Equipment Operator to verify the position of DH and HPI valves in the flowpath.
Use proper three-part communication for any necessary cues.CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Restore HPI Pump 1 breaker to service, if necessary.
.C.STANDARD:
Communicate with an EO to remove tags, rack in, and insert close power fuses on 4160 VAC breaker AClll.CUE: (If asked) The Shift Supervisor has given permission to remove the Safety tag from AClll breaker for HPI pump 1.SAT UNSAT JPM No. 91C Page 25 of 26 14. PERFORMANCE STEP: Close High Pressure Injection valves HP 2A, 2B, 2C, and 2D.STANDARD:
Visual verification of Green light is LIT on HIS HP2C and HIS HP2D.CUE: None.SAT UNSAT 15. PERFORMANCE STEP: Start HPI Pump 1..C.STANDARD:
Place HIS 1524 to START, then release. Observe the Red light goes ON and the Green light goes OFF.CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Throttle HP 2A, 2B, 2C, and 2D to establish injection.C........
flow.STANDARD:
Press the open pushbutton on HP 2C and HP 2D using HIS HP2C and HIS HP2D until flow is established.
COMMENT: Actual flow rate is. not critical at this step, provided some flow is provided.CUE: None.SAT UNSAT 17. PERFORMANCE STEP: Monitor incore thermocouples.
STANDARD:
Examine incore thermocouple temperatures on the PAM Panels.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 91 Page 26 of 26 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date JPM NEW 2B Page 10 of 17 JPM -Part B SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Recover From Inadvertent SFAS Incident Level 4 INITIAL CONDITION:
FPSS, any time in life ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
: 1. Insert the malfunctions listed below in the sequence listed.2. Perform Immediate Actions of DB-OP-02515, RC Pump and Motor Abnormal Operation.
: 3. Perform Immediate and Supplemental Actions of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture, Step 4.15.16.4. Place in hand and close MU 19.MALFUNCTIONS/FAILURE TO INSERT:* Insert malfunction L6P2C to fail SFAS Channel 2 containment pressure transmitter high.* Insert malfunction E60A to fail 120 VAC bus Y1.ACTION/CUES:
NOTE: Use proper 3-part communication for any necessary cues.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: NEW 2B Rev. 0 Page 11 of 20 TASK NO.: 013-021-04-0100 TASK DESCRIPTION:
Recover From Inadvertent SFAS Incident Level 4 K/A
 
==REFERENCE:==
 
013-XXX-A1.02 (3.9/4.2), 013-XXX-A2.06 (3.7/4.0), 013-XXX-A4.02 (4.3/4.4)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
25 minutes APPLICABILITY:
[X] RO [X] SRO TASK STANDARDS:
: 1. Containment Spray Pumps 1 and 2 have been stopped.2. SFAS has been reset.3. CCW to containment has been restored.4. Cooling has been restored to the control rod drive mechanisms.
REQUIRED MATERIALS:
DB-OP-06910, Trip Recovery, Rev. 0, Ch. 7 GENERAL
 
==REFERENCES:==
 
DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture, Rev. 5 DB-OP-02515, RC Pump and Motor Abnormal Operation, Rev. 1, Ch. 4 DB-OP-06405, Safety Features Actuation System Procedure, Rev. 2, Ch. 8 DB-OP-06910, Trip Recovery, Rev. 0, Ch. 7 INITIAL CONDITIONS:
A sequence of events has occurred resulting in an inadvertent actuation of SFAS Incident Levels 1-4 on SFAS Containment Pressure >38.4 psia. Immediate actions for DB-OP-02515, RC Pump and Motor Abnormal Operation, have been performed, and the plant has been stabilized in accordance with DB-OP-02000.
INITIATING CUES: The Shift Supervisor has directed you to perform recovery from SFAS Incident Level 4 in accordance with DB-OP-06910, Trip Recovery, and reset SFAS Channel 2 in accordance with DB-OP-06405, Safety Features Actuation System Procedure.(Hand a copy of DB-OP-06910 to the Examinee.)
JPM NEW 2B Page 12 of 17 INITIAL CONDITIONS:
A sequence of events has occurred resulting in an inadvertent actuation of SFAS Incident Levels 1-4 on SFAS Containment Pressure >38.4 psia. Immediate actions for DB-OP-02515, RC Pump and Motor Abnormal Operation, have been performed, and the plant has been stabilized in accordance with DB-OP-02000.
INITIATING CUES: The Shift Supervisor has directed you to perform recovery from SFAS Incident Level 4 in accordance with DB-OP-06910, Trip Recovery, and reset SFAS Channel 2 in accordance with DB-OP-06405, Safety Features Actuation System Procedure.
JPM NEW 2B Page 13 of 17 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure section.STANDARD:
Identifies DB-OP-06910, Section 6.0 as the correct procedure and section.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Verify containment pressure <18.4 psia.STANDARD:
Observes SFAS containment pressure indicators.
CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Depress the block button HIS 1533A for CS Pump 1..C.STANDARD:
HIS 1533A depressed and released.
Amber Block light goes BRIGHT.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Stop CS Pump 1 using HIS 1533..C.STANDARD:
HIS 1533 placed in stop and released.
Red light goes OFF, Green light goes ON. Pump amps decrease to 0.CUE: None.SAT UNSAT 5. PERFORMANCE STEP: Depress the block button HIS 1532A for CS Pump 2..C.STANDARD:
HIS 1532A depressed and released.
Amber Block light goes BRIGHT.CUE: None.SAT UNSAT JPM NEW 2B Page 14 of 17 6. PERFORMANCE STEP: Stop CS Pump 2 using HIS 1532..C.STANDARD:
HIS 1532 placed in stop and released.
Red light goes OFF, Green light goes ON. Pump amps decrease to 0.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Return to DB-OP-06910, Step 6.1.3.STANDARD:
Identifies the need to return to DB-OP-06910, Step 6.1.3.CUE: (If asked) The Shift Supervisor directs you to take all actions necessary to restore component cooling water to containment and to control rod drives.SAT UNSAT 8. PERFORMANCE STEP: Open CC 1407A, CC Wtr From CTMT Motor Operated Iso..C. Vlv., using HIS 1407A.STANDARD:
HIS 1407A open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Open CC 1407B, CC Wtr From CTMT Motor Operated Iso..C. Vlv., using HIS 1407B.STANDARD:
HIS 1407B open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 10. PERFORMANCE STEP: Open CC 1411A, CC Wtr From CTMT Motor Operated Iso..C. Vlv., using HIS 1411A.STANDARD:
HIS 1411A open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT JPM NEW 2B Page 15 of 17 JPM NEW 2B Page 15 of 17 11. PERFORMANCE STEP: Open CC 1411B, CC Wtr From CTMT Motor Operated Iso..C. Vlv., using HIS 1411B.STANDARD:
HIS 1411B open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Place HIS 1915, CRD CLNG Booster Pump 1, STANDARD:
HIS 1915 switch placed in lock out. Amber light CUE: None.in lock out.goes ON.13. PERFORMANCE STEP: Place HIS 1924, CRD CLNG Booster Pump 2, STANDARD:
HIS 1924 switch placed in lock out. Amber light CUE: None.SAT UNSAT in lock out.goes ON.SAT UNSAT 14. PERFORMANCE STEP: Open CC 1328, CCW to CRD Clng Booster Pump 1 Suct.,.C........
using HIS 1328.STANDARD:
HIS 1328 open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 15. PERFORMANCE STEP: Open CC 1338, CCW to CRD Clng Booster Pump 2 Suct.,.C........
using HIS 1338.STANDARD:
HIS 1338 open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Open CC 1567A, CCW to CRDM, using HIS 1567A..C.STANDARD:
HIS 1567A open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT JPM NEW 2B Page 16 of 17 17. PERFORMANCE STEP: Open CC 1567B, CCW to CRDM, using HIS 1567B..C.STANDARD:
HIS 1567B open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 18. PERFORMANCE STEP: Start the preferred CRD booster pump by placing the.C........
control switch in auto.STANDARD:
HIS 1915 placed in auto. Amber light goes OFF,then Green light goes OFF, and Red light goes ON.NOTE: Critical only if Steps 22 and 23 were performed.
CUE: None.SAT UNSAT 19. PERFORMANCE STEP: Place the standby CRD booster pump control switch in auto.STANDARD:
HIS 1924 placed in auto. Amber light goes OFF.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM NEW 2 Page 17 of 17 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO [ ] ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date JPM NEW ID Page 10 of 19 JPM -Part B SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Restore ICS Feedwater Subsystem to Full Automatic Control INITIAL CONDITION:
Any IC 50 to 100% power; below 100% power is preferable.
ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
: 1. Place SP-7B in hand and reduce to 50% valve position.2. Place SP-6B in hand.3. Place both feedwater demand hand/auto stations in hand and slowly reduce the output by 10% on each.MALFUNCTIONS/FAILURE TO INSERT: None.ACTION/CUES:
NOTE: Use proper 3-part communication for any necessary cues.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: NEW 1B Rev. 0 Page 11 of 20 TASK NO.: 041-005-04-0100, 041-011-01-0100, 041-013-04-0100 TASK DESCRIPTION:
Restore ICS Feedwater Subsystem to Full Automatic Control K/A
 
==REFERENCE:==
 
059-XXX-A4.10 (3.9/3.8), 059-XXX-A3.07 (3.4/3.5)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
APPLICABILITY:
[X] RO 16 minutes[ I SRO TASK STANDARDS:
1.2 .3 .Feedwater startup valve hand/auto station restored to automatic control.Feedwater main valve hand/auto station restored to automatic control.Feedwater demand hand/auto stations restored to automatic control.REOUIRED MATERIALS:
DB-OP-06401, Integrated Control System Operating Procedure, Rev. 2, Ch. 4 GENERAL
 
==REFERENCES:==
 
DB-OP-06401, Integrated Control System Operating Procedure, Rev. 2, Ch. 4 INITIAL CONDITIONS:
An event has occurred that has left the following ICS hand/auto stations in hand: both feedwater loop demands, SG 1 Main Feedwater Valve, SG 1 Startup Feedwater Valve. The event has been terminated and the cause of the event has been determined and corrected.
INITIATING CUES: The Shift Supervisor has directed you to restore the ICS Feedwater Subsystem to full automatic control using DB-OP-06401, Integrated Control System Operating Procedure.(Hand a copy of DB-OP-06401 to the examinee)
JPM NEW 1B Page 12 of 19 INITIAL CONDITIONS:
An event has occurred that has left the following ICS hand/auto stations in hand: both feedwater loop demands, SG 1 Main Feedwater Valve, SG 1 Startup Feedwater Valve. The event has been terminated and the cause of the event has been determined and corrected.
INITIATING CUES: The Shift Supervisor has directed you to restore the ICS Feedwater Subsystem to full automatic control using DB-OP-06401, Integrated Control System Operating Procedure.
JPM NEW 1B Page 13 of 19 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure section.STANDARD:
Identifies DB-OP-06401, Section 3.5, as the correct procedure and section.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Verify HC ICS20, Reactor Demand, is in auto.STANDARD:
Red light ON and White light OFF on HC ICS20.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Review Attachment 3, FIC ICS33A and B, Feedwater Startup Valves 2 and 1.STANDARD:
Operator refers to Attachment 3.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Monitor related DAAS points.STANDARD:
Operator refers to appropriate DAAS display points.NOTE: This step is optional.CUE: None.SAT UNSAT JPM NEW 1B Page 14 of 19 JPM NEW lB Page 14 of 19 5. PERFORMANCE STEP: Slowly adjust FIC ICS32B, Feedwater Demand, until.C. feedwater demand output is slightly greater than actual Feedwater flow.STANDARD:
SG 1 feedwater demand set for [(SG 1 FW Flow/7 mpph) x 100%]+5% / -0W.COMMENT: It is also acceptable to select measured variable on FIC ICS32B and adjust output until the pointer indicates slightly above the caret.CUE: None.Current FW Flow FW Demand Set_______mpph SDAT TTMNSAT 6. PERFORMANCE STEP:.C.Slowly open SP 7B by adjusting FIC ICS33B, Feedwater Startup Valve, while adjusting FIC ICS35B, Feedwater Main Valve, to maintain constant SG level.STANDARD:
SP 7B at 100% valve position with constant SG level.CUE: None.SAT UNSAT 7. PERFORMANCE STEP:.C.Depress and release AUTO on FIC ICS33B, FEEDWATER STARTUP VALVE.STANDARD:
Auto button depressed and released.
Red light ON and White light OFF on FIC ICS33B.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Route to Section 3.6 STANDARD:
Identifies Section 3.6 as the next applicable procedure section.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Verify FIC ICS33B, Feedwater Startup Valve is in auto.STANDARD:
Red light ON and White light OFF on FIC ICS33B.COMMENT: This action may not be performed since FIC ICS33B was just placed in auto in Step 7.CUE: None.SAT UNSAT JPM NEW IB Page 15 of 19 JPM NEW lB Page 15 of 19 10. PERFORMANCE STEP: Verify FIC ICS32B, Feedwater Demand, is in hand.STANDARD:
Red light OFF and White light ON on FIC ICS32B.COMMENT: This action may not be performed since FIC ICS32B position was verified in hand for Steps 5 through 7 above.CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Review Attachment 4, FIC ICS35A and B Feedwater Main Valve 2 and 1.STANDARD:
Operator refers to Attachment 4.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Monitor related DAAS points.STANDARD:
Operator refers to appropriate DAAS display points.NOTE: This step is optional.CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Adjust FIC ICS32B. Feedwater Demand. until measured.C..STANDARD: COMMENT: CUE: None.I...... variable on FIC ICS35B, Feedwater Main Valve is on the caret.Moving pointer on FIC ICS35B is positioned over the red fixed pointer (caret) within +/-5%.This action will also affect main feed pump speed.SAT UNSAT 14. PERFORMANCE STEP: Depress and release auto on FIC ICS35B, Feedwater.C. Main Valve.STANDARD:
Auto button depressed and released.
Red light ON and White light OFF on FIC ICS35B.CUE: None.SAT UNSAT JPM NEW 1B Page 16 of 19 15. PERFORMANCE STEP: Route to Section 3.8 STANDARD:
Identifies Section 3.8 as the next applicable procedure section.CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Verify FIC ICS33A&B, Feedwater Startup Valves are in auto.STANDARD:
Red light ON and White light OFF on FIC ICS33A&B.CUE: None.SAT UNSAT 17. PERFORMANCE STEP: Verify FIC ICS35A&B, Feedwater Main Valves are in auto.STANDARD:
Red light ON and White light OFF on FIC ICS35B.CUE: None.SAT UNSAT 18. PERFORMANCE STEP: Verify FIC ICS36A&B, Main Feed Pump ICS Controls are in auto.STANDARD:
Red light ON and White light OFF on FIC ICS36A&B.CUE: None.SAT UNSAT 19. PERFORMANCE STEP: Review Attachment 6, FIC ICS32A and B Feedwater Demand 2 and 1.STANDARD:
Operator refers to Attachment 6.CUE: None.SAT UNSAT 20. PERFORMANCE STEP: Monitor related DAAS points.STANDARD:
Operator refers to appropriate DAAS display points.NOTE: This step is optional.CUE: None.SAT UNSAT JPM NEW 1B Page 17 of 19 JPM NEW lB Page 17 of 19 21. PERFORMANCE STEP:.C.Adjust FIC ICS32B, Feedwater Demand until measured variable on FIC ICS32B is on the caret, OR measured variables are equal amounts above and below the caret on FIC ICS32B and FIC ICS32A.STANDARD:
Moving pointer on FIC ICS32B is positioned over the caret within +/-5%, OR moving pointers on FIC ICS32B and FIC ICS32A are equal amounts above and below the caret.NOTE: FIC ICS32B and FIC ICS32A may be placed in auto in either order.CUE: None.SAT UNSAT 22. PERFORMANCE STEP:.C.Adjust FIC ICS32A, Feedwater Demand until measured variable on FIC ICS32A is on the caret, OR measured variables are equal amounts above and below the caret on FIC ICS32B and FIC ICS32A.STANDARD:
Moving pointer on FIC ICS32A is positioned over the caret within +/-5%, OR moving pointers on FIC ICS32B and FIC ICS32A are equal distances above and below the caret.NOTE: FIC ICS32B and FIC ICS32A may be placed in auto in either order.CUE: None.SAT UNSAT 23 PERFORMANCE STEP:.C.IF FIC ICS32B and FIC ICS32A are equal amounts above and below the caret, THEN adjust HIC ICS30 Stm Gen Load Ratio until FIC ICS32B and FIC ICS32A measured variables are on the caret.STANDARD:
Moving pointers on FIC ICS32B and FIC ICS32A are positioned over the caret within +/-5%.NOTE: Examinee may elect to repeat steps 21 and 22 if ICS 32A&B pointers do not end up on the caret.CUE: None.SAT UNSAT 24. PERFORMANCE STEP:........ ........Depress and release auto on FIC ICS32B, Feedwater Demand.STANDARD: Auto button depressed and released.
Red light ON and White light OFF on FIC ICS32B.NOTE: FIC ICS32B and FIC ICS32A may be placed in auto in either order.CUE: None.SAT UNSAT JPM NEW 1B Page 18 of 19 25. PERFORMANCE STEP: Depress and release auto on FIC ICS32A, Feedwater.C. Demand.STANDARD:
Auto button depressed and released.
Red light ON and White light OFF on FIC ICS32A.NOTE: FIC ICS32B and FIC ICS32A may be placed in auto in either order.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM NEW 1 Page 19 of 19 VERIFICATION OF COMPLETION Operator SSN License: Evaluator Date[ I RO [ ] SRO [ ] ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date JPM No. 44B Page 6 of 12 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Loss of Instrument Air Actions from the Control Room.INITIAL CONDITION:
100% any time in life.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
Station Air Compressor 2 running.MALFUNCTIONS/FAILURE TO INSERT: Leak on Instrument Air System. TVKFO701/ramp to 0.05 over 2 minutes.ACTION/CUES:
: 1. Step 6: SA6445 is closed.2. Step 6: SA236 is closed.3. Step 7: Checking for air leaks.4. Step 8: SA18 and SA20 closed, TAKF0110/0.
-DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 44B Rev. 08 Page 7 of 12 TASK NO.: 078-009-04-0100 TASK DESCRIPTION:
Loss of Instrument Air Actions from the Control Room K/A
 
==REFERENCE:==
 
000-065-EA1.04 (3.5/3.4), 000-065-EA2.06 (3.6/4.2), 000-065-GEN.06 (3.1/3.3)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
5 minutes APPLICABILITY:
[XI RO [XI SRO TASK STANDARDS:
Trip the reactor and actuate SFRCS when air pressure is 75 psig.REOUIRED MATERIALS:
DB-OP-02528, Loss of Instrument Air Abnormal Procedure, Revision 02, C-6 GENERAL
 
==REFERENCES:==
 
DB-OP-02528, Loss of Instrument Air Abnormal Procedure, Revision 02, C-6 INITIAL CONDITIONS:
The plant is operating in Mode 1. All systems in a normal line up.INITIATING CUES: The following annunciator alarms are received:-STA AIR HDR PRESS LO (9-3-E)-INSTR AIR HDR PRESS LO (9-1-F)
JPM No. 44B INITIAL CONDITIONS:
The plant is in Mode 1. All systems in a normal line up.Page 8 of 12 INITIATING CUES: The following annunciator alarms are received:-STA AIR HDR PRESS LO (9-3-E)-INSTR AIR HDR PRESS LO (9-1-F)
JPM No. 44B Page 9 of 12 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: l1. PERFORMANCE STEP: Locate the correct procedure.
STANDARD:
Identifies DB-OP-02528, Loss of Instrument Air, as the correct procedure.
COMMENT: Sequence NOT required for this JPM.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Perform Immediate Actions.STANDARD:
Check PI 810 air pressure is > 75 psig and for secondary upset.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Verify the standby station air compressor and emergency instrument air compressor have started.STANDARD:
Verify all air compressors are running/Red lights LIT.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Start temp. diesel air compressor.
STANDARD:
Direct EO to start compressor.
CUE: Temp. diesel air compressor is NOT available.
SAT UNSAT 5. PERFORMANCE STEP: Inform all personnel per procedure.
STANDARD:
Announce over the Gai-Tronics.
CUE: None.SAT UNSAT JPM No. 44B Page 10 of 12 JPM No. 44B Page 10 of 12 6. PERFORMANCE STEP: Dispatch an Equipment Operator to verify SA 6445, and SA 236 SA/IA cross-tie valve, are closed.STANDARD:
Verbal communication to verify SA 6445 CLOSED by checking position of NV 6445 OR close SA 234. Verify SA 236 is CLOSED.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Dispatch operators to locate major air leaks.STANDARD:
Operators dispatch to locate major air leaks in the plant.COMMENT: This step may not be performed if DB-OP-02528, Step 4.1.7, is strictly adhered to. This step is not mandatory for satisfactory test completion.
CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Dispatch an operator to close SA 18 and SA 20.STANDARD:
Verbal communication with Equipment Operator to CLOSE SA 18 and SA 20.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Manually TRIP the reactor when IA pressure drops to.C........
75 psig.STANDARD:
Push either REACTOR TRIP button on control board.CUE: None.SAT UNSAT 10. PERFORMANCE STEP: Initiate AFW flow and isolate both SGs..C.STANDARD:
Depress SFRCS MANUAL ACTUATION and ISOLATION switches, HIS 6403 and 6404.CUE: None.SAT UNSAT JPM No. 44B Page 11 of 12 11. PERFORMANCE STEP: Go to DB-OP-02000, RPS, SFAS, SFRCS or SG Tube Rupture Procedure.
STANDARD:
Refer to procedure for reactor trip or SFRCS trip.CUE: DB-OP-02000 is in progress.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 44 Page 12 of 12 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date JPM No. 85C Page 10 of 16 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Purge Containment in Mode 5.INITIAL CONDITION:
Any mode.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
-Turn off CTMT Purge Supply and Exhaust Fans.-Close dampers CV 5004, 5016, 5009 and 5021.-Install fuses in SFAS cabinets.-Verify dampers CV 5005, 5006, 5007, and 5008 are closed.MALFUNCTIONS/FAILURE TO INSERT: Prevent start of CTMT Purge Supply Fan by closing air valve to supply damper.-IMF CAV7B ACTION/CUES:
: 1. Step 8, CUE: The only item found out of position was DP6802, circuit 1, which was found open.2. Step 9, ACTION: Remove the malfunction (DMF CAV7B).CUE: DP6802 circuit 1 has been closed.
JPM No. 85C Page 11 of 16 DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 85C Rev. 05 Page 11 of 16 TASK NO.: 029-010-01-0100 TASK DESCRIPTION:
Purge Containment in Mode 5 K/A
 
==REFERENCE:==
 
000-060-EA1.02 (2.9/3.1);
000-060-EA2.06 (3.6/3.8);
029-000-K1.03 (3.6/3.8);
029-000-GEN.09 (2.9/3.1)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
APPLICABILITY:
[XI RO 18 minutes[XI SRO TASK STANDARDS:
Initiate containment vessel purge.REOUIRED MATERIALS:
DB-OP-06503, Containment Purge System Procedure, Revision 00, C-7 GENERAL
 
==REFERENCES:==
 
DB-OP-06503, Containment Purge System Procedure, Revision 00, C-7 INITIAL CONDITIONS:
The plant is in Mode 5. The Containment Purge System had been running on containment.
At the beginning of last shift, containment purge was stopped and purge was started on the Mechanical Penetration Rooms. At the end of last shift, the purge was stopped.INITIATING CUES: The Shift Supervisor directs you to start a containment vessel purge per DB-OP-06503, Containment Purge System Procedure.(Hand copy of DB-OP-06503 to examinee.)
JPM No. 85C Page 12 of 16 INITIAL CONDITIONS:
The plant is in Mode 5. The Containment Purge System had been running on containment.
At the beginning of last shift, containment purge was stopped and purge was started on the Mechanical Penetration Rooms. At the end of last shift, the purge was stopped.INITIATING CUES: The Shift Supervisor directs you to start a containment vessel purge per DB-OP-06503, Containment Purge System Procedure.
JPM No. 85C Page 13 of 16 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure.
STANDARD:
Identifies Section 3.1 of DB-OP-06503, Containment Purge System Procedure, as the correct section.COMMENT: When correct section has been located, provide CUE to trainee.CUE: All prerequisites have been completed.
SAT UNSAT 2. PERFORMANCE STEP: Make a plant announcement.
STANDARD:
Use the GAITRONICS to make the proper announcement.
CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Open the purge CTMT isolation valves..C.STANDARD:
Press the OPEN pushbutton on HIS 5005, 5006, 5007, and 5008.COMMENT: Sequence NOT required.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Start the CTMT purge exhaust fan.STANDARD:
Turn handswitch HIS 5013 to START.CUE: None.SAT UNSAT JPM No. 85C Page 14 of 16 5. PERFORMANCE STEP: Verify automatic actions occur.STANDARD:
Verifies red indicating light for CTMT purge exhaust fan ON.COMMENT: The fan will start in approximately 120 seconds.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Start the CTMT purge supply fan.STANDARD:
Within 20 seconds after the exhaust fan starts, turn handswitch HIS 5003 to START.COMMENT: Fan is failed.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: GO TO Section 4.3.STANDARD:
Verify the CTMT Purge Exhaust Fan is off as well as the CTMT Purge Supply fan.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Send an EO to investigate the problem with the fan.C .per Attachment 4.STANDARD:
Verbal communication with an Equipment Operator to investigate the problem.CUE: (If asked) The Shift Supervisor directs you to use an EO to check the problem.SAT UNSAT 9. PERFORMANCE STEP: Direct the EO to open the supply dame ir ;ve-.........c ........C do! Jreak, DP GO , U I STANDARD:
Verbal communication with Equipment Operator to c CUE: (If asked) The Shift Supervisor directs you to direct the EO to close breaker DP6802, circuit 1, and he will document the breaker being out of position.SAT UNSAT JPM No. 85C Page 15 of 16 10. PERFORMANCE STEP: Start CTMT purge exhaust fan..C.STANDARD:
Turn handswitch HIS 5013 to START.COMMENT: The fan will start in approximately 120 seconds.CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Verify automatic actions occur.STANDARD:
Verifies red indicating light for CTMT purge exhaust fan is ON.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Start the CTMT purge supply fan..C.STANDARD:
Within 20 seconds after the exhaust fan is running, turn handswitch HIS 5003 to START.COMMENT: Fan is NOT failed.CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Verify automatic actions occur..C.STANDARD:
Visually verify supply fan red light ON.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 85C Page 16 of 16 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 27 Rev. 09 Page 1 of 6 TASK NO.: 076-004-04-0100 TASK DESCRIPTION:
Use Circ Water to Supply Service Water Primary Loads K/A
 
==REFERENCE:==
 
000-062, GEN.06 (3.4/3.6)APPLICABLE METHOD OF TESTING: Simulate performance In-plant TIME FOR COMPLETION:
13 minutes APPLICABILITY:
[X] RO [X] SRO TASK STANDARDS:
Circ. Water System supplying SW primary loads.REQUIRED MATERIALS:
DB-OP-02511, Loss of Service Water Pumps/System, Revision 01, C-4 GENERAL
 
==REFERENCES:==
 
DB-OP-02511, Loss of Service Water Pumps/System, Revision 01, C-4 INITIAL CONDITIONS:
The plant is in Mode 3 with a loss of all service water in progress.INITIATING CUES: The Shift Supervisor directs you to line up circulating water to supply Loop 2 primary loads, per Attachment 7 of DB-OP-02511.(Hand examinee a copy of DB-OP-02511.)
JPM No. 27 Page 2 of 6 INITIAL CONDITIONS:
The plant is in Mode 3, with a loss of all service water in progress.INITIATING CUES: The Shift Supervisor directs you to line up circulating water to supply Loop 2 primary loads, per Attachment 7 of DB-OP-02511.
JPM No. 27 Page 3 of 6 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Obtain a key for the intake structure..C.STANDARD:
Obtain a key from the Control Room key locker.COMMENT: Step is not critical if trainee uses the card reader to enter the service water tunnel from the Turbine Building.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Verify CT 2955, TPCW HX SUPPLY FROM CIRC WTR, is OPEN..STANDARD: CUE: Verify valve position by pointing (locally) or requesting indicating light from the Control Room.CT 2955 local position indicator is pointing to OPEN.HIS 2955 Red light is LIT.NV 2955 Red light is LIT (if asked).SAT UNSAT 3. PERFORMANCE STEP: Verify CT 56, CIRCULATING WATER SUPPLY TO TURBINE PLANT COOLING WATER HEAT EXCHANGER STOP VALVE, is OPEN.STANDARD:
Verify valve position by local position indicator.
CUE: CT 56 valve indicator is pointing to "0".SAT UNSAT 4. PERFORMANCE STEP: Isolate service water to secondary loads.STANDARD:
Close SW 155, SW TO BACKWASH RECEIVER TANK SUMP PUMP DISCHARGE ISOLATION.
CUE: SW 155 has been rotated clockwise and the valve stem is IN.SAT UNSAT JPM No. 27 Page 4 of 6 JPM No. 27 Page 4 of 6 5. PERFORMANCE STEP: Isolate service water to secondary loads..C.STANDARD:
Close the following valves: SW 51, TPCW HEAT EXCHANGER 1 INLET ISOLATION VALVE.SW 52, TPCW HEAT EXCHANGER 2 INLET ISOLATION VALVE.SW 53, TPCW HEAT EXCHANGER 3 INLET ISOLATION VALVE.CUE: SW 51 has been rotated clockwise and the valve position indicator moves from vertical to horizontal.
SW 52 has been rotated clockwise and the valve position indicator moves from vertical to horizontal.
SW 53 has been rotated clockwise and the valve position indicator moves from vertical to horizontal.
SAT UNSAT 6. PERFORMANCE STEP: Isolate service water to secondary loads.STANDARD: Close AS 283, SERVICE WATER CONTROL VALVE ISOLATION VALVE (Blowdown Mix Condenser).
COMMENT: AS 283 is located on the 585'level, Aux. Boiler Room, south wall.CUE: AS 283 has been rotated clockwise and the valve stem is IN.SAT UNSAT 7. PERFORMANCE STEP: Open Breaker BF 1277..C.STANDARD:
Take breaker handle to OFF/TRIPPED position.CUE: BF 1277 breaker handle has been pushed down and indicates OFF/TRIPPED.
SAT UNSAT JPM No. 27 Page 5 of 6 8. PERFORMANCE STEP: Open SW 1395, TPCW HEAT EXCHANGE INLET HEADER ISO.C. VALVE.STANDARD: Engage handwheel, turn counterclockwise on the handwheel for SW 1395.COMMENTS:
Indicating lights off because breaker has just been opened.CUE: SW 1395 handwheel clutch has been DEPRESSED, the handwheel has been turned counterclockwise, and the SW 1395 position indicator is pointing up.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 27 Page 6 of 6 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: NEW 3-1 Rev. 0 Page 1 of 21 TASK NO.: 062-028-01-0100 TASK DESCRIPTION:
Perform a Local Dead 13.8 KV Bus Transfer Note: Use JPM NEW 03-2 if train is protected; use JPM NEW 03-2 if Train 1 is protected.
K/A
 
==REFERENCE:==
 
062-XXX, A2.15 (2.8/3.2), A4.07 (3.1/3.1)APPLICABLE METHOD OF TESTING: Simulate In-Plant Alternate procedure TIME FOR COMPLETION:
APPLICABILITY:
[X] RO 20 minutes[XI SRO TASK STANDARDS:
: 1. Recognize out of phase condition of bus sources.2. Transfer Bus A source to Startup Transformer 02.REOUIRED MATERIALS:
DB-OP-06314, 13.8 KV Bus Switching Procedure, Revision 01 GENERAL
 
==REFERENCES:==
 
DB-OP-06314, 13.8 KV Bus Switching Procedure, Revision 01 INITIAL CONDITIONS:
An event has occurred that resulted in evacuation of the Control Room.Local control has been established at the auxiliary shutdown panel and the plant has been stabilized.
EDG 1 is supplying power to 4160 VAC Buses C1 and C2. EDG 2 is supplying power to 4160 VAC Buses Dl and D2.All load breakers have been opened on A and B buses.13.8 KV Bus A has been reenergized from Startup Transformer 01.Bus B has been reenergized from Startup Transformer 02.13.8 KV As a result of unusual indications on Startup Transformer 01, Startup Transformer 01 must be deenergized.
In order to permit Startup Transformer 01 to be deenergized, 13.8 KV Bus A must be transferred to Startup Transformer
: 02.
JPM NEW 3-1 Page 2 of 21 INITIATING CUES: You have been directed to perform a local live bus transfer of 13.8 KV Bus A to Startup Transformer 02 using DB-OP-06314, 13.8 KV Bus Switching Procedure.(Hand a copy of DB-OP-06314 to the examinee.)
JPM NEW 3-1 Page 3 of 21 INITIAL CONDITIONS:
An event has occurred that resulted in evacuation of the Control Room.Local control has been established at the auxiliary shutdown panel and the plant has been stabilized.
EDG 1 is supplying power to 4160 VAC Buses C1 and C2. EDG 2 is supplying power to 4160 VAC Buses D1 and D2.All load breakers have been opened on A and B buses.13.8 KV Bus A has been reenergized from Startup Transformer
: 01. 13.8 KV Bus B has been reenergized from Startup Transformer 02.As a result of unusual indications on Startup Transformer 01, Startup Transformer 01 must be deenergized.
In order to permit Startup Transformer 01 to be deenergized, 13.8 KV Bus A must be transferred to Startup Transformer 02.INITIATING CUES: You have been directed to perform a local live bus transfer of 13.8 KV Bus A to Startup Transformer 02 using DB-OP-06314, 13.8 KV Bus Switching Procedure.
JPM NEW 3-1 Page 4 of 21 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: l1. PERFORMANCE STEP: Determine the correct procedure section.STANDARD:
Determine that Section 4.1 is the correct section.CUE: All prerequisites are complete.(If asked) The Shift Supervisor directs you to use source Startup Transformer 02.SAT UNSAT 2. PERFORMANCE STEP: Verify 25SWA/LOCAL Synchro Check Selector in OFF.STANDARD:
Observe the position of 25SWA/LOCAL Synchro Check Selector to be OFF (and place in OFF if not already in that position).
CUE: 25SWA/LOCAL Synchro Check Selector indicates OFF.SAT UNSAT 3. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch A Bus positioned the same as HS 6294 or as directed by the Shift Supervisor.
STANDARD: Observe the position of the 10/LOCAL Reserve Source Selector Switch A Bus.CUE: (If asked) The Shift Supervisor directs you to leave the local Reserve Source Selector Switch in the X01 or X02 position.SAT UNSAT 4. PERFORMANCE STEP: Place DSA/LOCAL in LOCAL..C.STANDARD:
Place the DSA/LOCAL switch on C3610 to the LOCAL position.CUE: DSA/LOCAL switch has been placed in LOCAL.SAT UNSAT JPM NEW 3-1 Page 5 of 21 5. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HX02A in LOCAL.STANDARD:
Place the emergency control transfer switch for HX02A in LOCAL on Cubicle 4 of A bus.CUE: HX02A emergency control transfer switch has been placed in LOCAL.SAT UNSAT 6. PERFORMANCE STEP: Place the emergency control transfer switch for HXllA in LOCAL.STANDARD: Place the emergency control transfer switch for HXllA in LOCAL on Cubicle 9 of A Bus.CUE: HXl1A emergency control transfer switch has been placed in LOCAL.SAT UNSAT 7. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HX01A in LOCAL.STANDARD:
Place the emergency control transfer switch for HXO1A in LOCAL on Cubicle 11 of A Bus.CUE: HXO1A Emergency Control Transfer Switch has been placed in LOCAL.SAT UNSAT 8. PERFORMANCE STEP: Visually check Synchro Check Relay 25 contacts open.STANDARD: Observe the condition of Synchro Check Relay 25 contacts (cubicle 5 upper left window.)CUE: Synchro Check Relay 25 contacts indicate open.COMMENT: A safe stool for observing the relay 25 contact position is located in the NE corner of the room behind 4160 VAC bus C1.Extreme caution must be used when manipulating the stool near switchgear cabinets to prevent bumping cabinet doors and causing relay actuations.
SAT UNSAT JPM NEW 3-1 Page 6 of 21 JPM NEW 3-1 Page 6 of 21 9. PERFORMANCE STEP: Turn 25SWA/LOCAL, Synchro Check Selector to the.C........
desired source and wait 15 seconds.STANDARD: Place 25SWA/LOCAL, Synchro Check Selector to the X02 position and wait 15 seconds for the Synchro Check Relay 25 contacts to respond.COMMENT: If sources are out of phase, the relay will not respond.CUE: Switch 25SWA/LOCAL has been rotated to the X02 position.
Fifteen seconds have elapsed. Synchro Check Relay contacts indicate open.SAT UNSAT 10. PERFORMANCE STEP:.C.Notify the Shift Supervisor that the synchro check relay contacts did not close.STANDARD:
Notify the Shift Supervisor of relay response.CUE: Shift Supervisor acknowledges that the synchro check relay contacts did not close and directs you to perform a dead bus transfer.SAT UNSAT 11. PERFORMANCE STEP: Route to Section 4.3, Local Dead Bus A Transfer..C.STANDARD: Determine that Section 4.3, Local Dead Bus A Transfer, is the correct section.COMMENT: Repeat initiating cues as necessary for procedure Steps 4.3.1 and 4.3.2 CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Verify 25SWA/LOCAL Synchro Check Selector in OFF.STANDARD: Observe the position of 25SWA/LOCAL Synchro Check Selector to be OFF (and place in OFF if not already in that position).
CUE: 25SWA/LOCAL Synchro Check Selector indicates X02. 25SWA/LOCAL Synchro Check Selector has been rotated to OFF.SAT UNSAT JPM NEW 3-1 Page 7 of 21 13. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch A Bus positioned the same as HS 6294 or as directed by the Shift Supervisor.
STANDARD: Observe the position of the 10/LOCAL Reserve Source Selector Switch A Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section.CUE: (If asked) the Shift Supervisor directs you to leave the local Reserve Source Selector Switch in the X01 or X02 position.SAT UNSAT 14. PERFORMANCE STEP: Place DSA/LOCAL in LOCAL..C.STANDARD:
Place the DSA/LOCAL switch on C3610 to the LOCAL position.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: DSA/LOCAL switch [is/has been placed] in LOCAL.SAT UNSAT 15. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HX02A in LOCAL.STANDARD: Place the emergency control transfer switch for HX02A in LOCAL on Cubicle 4 of A Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: HX02A emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT JPM NEW 3-1 Page 8 of 21 JPM NEW 3-1 Page 8 of 21 16. PERFORMANCE STEP: Place the emergency control transfer switch for HX1lA in LOCAL.STANDARD: Place the emergency control transfer switch for HXllA in LOCAL on Cubicle 9 of A Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section.CUE: HX1lA emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT 17. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HX0lA in LOCAL.STANDARD: Place the emergency control transfer switch for HXO1A in LOCAL on cubicle 11 of A Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: HXO1A emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT 18. PERFORMANCE STEP: Verify the following equipment out of service: RCP 1-1, RCP 2-2, Circ. Water Pump 1 and Circ. Water Pump 3.STANDARD: Verify open indication on the breakers for RCP 1-1, RCP 2-2, Circ. Water Pump 1 and Circ. Water Pump 3.COMMENT: Trainee may not perform this step due to initial conditions.
CUE: Green Green Green Water Green Water light is LIT, Red light is OFF on HA01, breaker for RCP 1-1.light is LIT, Red light is OFF on HA03, breaker for RCP 2-2.light is LIT, Red light is OFF on HA08, breaker for Circ.Pump 1.light is LIT, Red light is OFF on HA12, breaker for Circ.Pump 3.SAT UNSAT JPM NEW 3-1 Page 9 of 21 19. PERFORMANCE STEP: Trip the following load breakers:
HAAC, HAAE4, HAAE2 and HAAE3.STANDARD:
Verify open indication on Breakers HAAC, HAAE4, HAAE2 and HAAE3.COMMENT: Trainee may not perform this step due to initial conditions.
CUE: Green light is LIT, Red light is OFF on HAAC.Green light is LIT, Red light is OFF on HAAE4.Green light is LIT, Red light is OFF on HAAE2.Green light is LIT, Red light is OFF on HAAE3.SAT UNSAT 20. PERFORMANCE STEP: Open Source Breaker HX01A..C.STANDARD:
Place handswitch on Cubicle 11 of Bus A (HXOlA) to TRIP, and release.CUE: Handswitch has been placed in TRIP and released.
Green light LIGHTS and Red light goes OFF.SAT UNSAT 21. PERFORMANCE STEP: Turn 25SWA/LOCAL, Synchro Check Selector to the.C ........ desired source.STANDARD:
Place 25SWA/LOCAL, Synchro Check Selector to the X02 position.COMMENT: No check of synchro check relay contact position is required for dead bus transfer.CUE: 25SWA/LOCAL has been placed in the X02 position.SAT UNSAT 22. PERFORMANCE STEP: Close Source Breaker HX02A..C.STANDARD:
Place handswitch on cubicle 4 of Bus A (HX02A) to CLOSE and release.CUE: Handswitch has been placed to CLOSE and released.
RED light LIGHTS and Green light goes OFF.SAT UNSAT JPM NEW 3-1 Page 10 of 21 23. PERFORMANCE STEP: Turn 25SWA/LOCAL, Synchro Check Selector to OFF.STANDARD:
Place 25SWA/LOCAL, Synchro Check Selector to the OFF position.CUE: 25SWA/LOCAL has been placed in the OFF position.SAT UNSAT 24. PERFORMANCE STEP: Verify normal system voltage on EI 6256, A Bus Kilovolts.
STANDARD:
Observe 13.8 KV Bus A indicates approximately 13.8 KV on Cubicle 5.COMMENT: Since the Control Room is unoccupied, the examinee will either read the voltage on the local meter or ask the Shift Supervisor for guidance.
Either action is acceptable.
CUE: No one is available to read El 6256. (If asked) The Shift Supervisor directs you to use the local indicator to check bus voltage. The phase select switch has been rotated [through all three phases] and [each phase] indicates approximately 13.8 Kilovolts.
SAT UNSAT 25. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch A Bus is in the X01 position.STANDARD:
Observe 10/LOCAL, Reserve Source Selector Switch Bus A is in the X01 position.COMMENT: Since Startup Transformer 01 will be deenergized, it is acceptable for the examinee to omit this step.CUE: (If asked) The Shift Supervisor directs you to leave the local reserve source selector switch in the X01 or X02 postion.SAT UNSAT TERMINATING CUES: This JPM is complete.COMMENT: Please ensure the stool, if used, is carefully returned to its storage location and secured.END TIME DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: NEW 03-2 Rev. 0 Page 11 of 24 TASK NO.: 062-028-01-0100 TASK DESCRIPTION:
Perform a Local Dead 13.8 KV Bus Transfer Note: Use JPM NEW 03-1 if Train 2 is Train 1 is protected.
protected; use JPM NEW 03-2 if K/A
 
==REFERENCE:==
 
062-XXX, A2.15 (2.8/3.2), A4.07 (3.1/3.1)APPLICABLE METHOD OF TESTING: Simulate In-Plant Alternate procedure TIME FOR COMPLETION:
APPLICABILITY:
[XI RO TASK STANDARDS:
20 minutes[XI SRO 1. Recognize out of phase condition of bus sources.2. Transfer Bus B source to Startup Transformer 01.REQUIRED MATERIALS:
DB-OP-06314, 13.8 KV Bus Switching Procedure, Revision 01 GENERAL
 
==REFERENCES:==
 
DB-OP-06314, 13.8 KV Bus Switching Procedure, Revision 01 INITIAL CONDITIONS:
An event has occurred that resulted in evacuation of the Control Room.Local control has been established at the auxiliary shutdown panel and the plant has been stabilized.
EDG 1 is supplying power to 4160 VAC Buses C1 and C2. EDG 2 is supplying power to 4160 VAC Buses D1 and D2.All load breakers have been opened on A and B buses.13.8 KV Bus A has been reenergized from Startup Transformer 01.Bus B has been reenergized from Startup Transformer 02.13.8 KV As a result of unusual indications on Startup Transformer 02, Startup Transformer 02 must be deenergized.
In order to permit Startup Transformer 02 to be deenergized, 13.8 KV Bus B must be transferred to Startup Transformer
: 01.
JPM NEW 3-2 INITIATING CUES: Page 12 of 21 You have been directed to perform a local live bus transfer of 13.8 KV Bus B to Startup Transformer 01 using DB-OP-06314, 13.8 KV Bus Switching Procedure.(Hand a copy of DB-OP-06314 to the examinee.)
JPM NEW 3-2 Page 13 of 21 INITIAL CONDITIONS:
An event has occurred that resulted in evacuation of the Control Room.Local control has been established at the auxiliary shutdown panel and the plant has been stabilized.
EDG 1 is supplying power to 4160 VAC Buses C1 and C2. EDG 2 is supplying power to 4160 VAC Buses Dl and D2.All load breakers have been opened on A and B buses.13.8 KV Bus A has been reenergized from Startup Transformer
: 01. 13.8 KV Bus B has been reenergized from Startup Transformer 02.As a result of unusual indications on Startup Transformer 02, Startup Transformer 02 must be deenergized.
In order to permit Startup Transformer 02 to be deenergized, 13.8 KV Bus B must be transferred to Startup Transformer 01.INITIATING CUES: You have been directed to perform a local live bus transfer of 13.8 KV Bus B to Startup Transformer 01 using DB-OP-06314, 13.8 KV Bus Switching Procedure.
JPM NEW 3-2 Page 14 of 21 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
I START TIME: i 1. PERFORMANCE STEP: Determine the correct procedure section.STANDARD:
Determine that Section 4.2 is the correct section.CUE: All prerequisites are complete. (If asked) The Shift Supervisor desires you to use source breaker KXOiB.SAT UNSAT 2. PERFORMANCE STEP: Verify 25SWB/LOCAL Synchro Check Selector in OFF.STANDARD:
Observe the position of 25SWB/LOCAL Synchro Check Selector to be OFF (and place in OFF if not already in that position).
CUE: 25SWB/LOCAL Synchro Check Selector indicates OFF.SAT UNSAT 3. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch B Bus positioned the same as HS 6295 or as directed by the Shift Supervisor.
STANDARD: Observe the position of the 10/LOCAL Reserve Source Selector Switch B Bus.CUE: (If asked) The Shift Supervisor directs you to leave the local Reserve Source Selector Switch in the X01 or X02 position.SAT UNSAT 4. PERFORMANCE STEP: Place DSB/LOCAL in LOCAL..C.STANDARD:
Place the DSB/LOCAL switch on C3611 to the LOCAL position.CUE: DSB/LOCAL switch has been placed in LOCAL.SAT UNSAT 5. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HX01B in LOCAL.STANDARD: Place the emergency control transfer switch for HXO1B in LOCAL on Cubicle 11 of B Bus.CUE: HXOlB emergency control transfer switch has been placed in LOCAL.SAT UNSAT JPM NEW 3-2 Page 15 of 21 JPM NEW 3-2 Page 15 of 21 6. PERFORMANCE STEP: Place the emergency control transfer switch for HXllB in LOCAL.STANDARD: Place the emergency control transfer switch for HXllB in LOCAL on Cubicle 9 of B Bus.CUE: HXl1B emergency control transfer switch has been placed in LOCAL.SAT UNSAT 7. PERFORMANCE STEP:.C.Place the emergency control transfer Switch for HX02B in LOCAL.STANDARD: Place the emergency control transfer switch for HX02B in LOCAL on Cubicle 4 of B Bus.CUE: HX02B emergency control transfer switch has been placed in LOCAL.SAT UNSAT 8. PERFORMANCE STEP: Visually check Synchro Check Relay 25 contacts open.STANDARD: Observe the condition of Synchro Check Relay 25 contacts (Cubicle 5 upper left window.)COMMENT: A safe stool for observing the Relay 25 contact position is located in the NE corner of the room north of 4160 VAC Bus Dl. Extreme caution must be used when manipulating the stool near switchgear cabinets to prevent bumping cabinet doors and causing relay actuations.
CUE: Synchro Check Relay 25 contacts indicate open.SAT UNSAT 9. PERFORMANCE STEP:.C.Turn 25SWB/LOCAL, Synchro Check Selector to the desired source and wait 15 seconds.STANDARD: Place 25SWB/LOCAL, Synchro Check Selector to the X01 position and wait 15 seconds for the Synchro Check Relay 25 contacts to respond.COMMENT: If sources are out of phase, the relay will not respond.CUE: Switch 25SWB/LOCAL has been placed in X01. Fifteen seconds have elapsed. Synchro check relay contacts indicate open.SAT UNSAT JPM NEW 3-2 Page 16 of 21 JPM NEW 3-2 Page 16 of 21 10. PERFORMANCE STEP: Notify the Shift Supervisor that the synchro check.C. selector relay contacts did not close.STANDARD:
Notify the Shift Supervisor of relay response.CUE: Shift Supervisor acknowledges that the synchro check relay contacts did not close and directs you to perform a dead bus transfer.SAT UNSAT 11. PERFORMANCE STEP: Route to Section 4.4, Local Dead Bus B Transfer.STANDARD: Determine that Section 4.4, Local Dead Bus B Transfer, is the correct section.COMMENT: Repeat initiating cues as necessary for procedure Steps 4.4.1 and 4.4.2 CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Verify 25SWB/LOCAL Synchro Check Selector in OFF.STANDARD: Observe the position of 25SWB/LOCAL Synchro Check Selector to be OFF (and place in OFF if not already in that position).
CUE: 25SWB/LOCAL Synchro Check Selector indicates X01. 25SWB/LOCAL Synchro Check Relay has been rotated to OFF.SAT UNSAT 13. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch B Bus positioned the same as HS 6295 or as directed by the Shift Supervisor.
STANDARD: Observe the position of the 10/LOCAL Reserve Source Selector Switch B Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section.CUE: (If asked) the Shift Supervisor directs you to leave the local Reserve Source Selector Switch in the X01 or X02 position.SAT UNSAT JPM NEW 3-2 Page 17 of 21 14. PERFORMANCE STEP: Place DSB/LOCAL in LOCAL..C.STANDARD:
Place the DSB/LOCAL switch on C3611 to the LOCAL position.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: DSB/LOCAL switch [is/has been placed] in LOCAL.SAT UNSAT 15. PERFORMANCE STEP: Place the emergency control transfer switch for.C........
HX01B in LOCAL.STANDARD:
Place the emergency control transfer switch for HXO1B in LOCAL on Cubicle 11 of B Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: HXO1B emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT 16. PERFORMANCE STEP: Place the emergency control transfer switch for HXllB in LOCAL.STANDARD:
Place the emergency control transfer switch for HXllB in LOCAL on Cubicle 9 of B Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section.CUE: HXl1B emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT JPM NEW 3-2 Page 18 of 21 17. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HX02B in LOCAL.STANDARD: Place the emergency control transfer switch for HX02B in LOCAL on Cubicle 4 of B Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: HX02B emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT 18. PERFORMANCE STEP: Verify the following equipment out of service: RCP 1-2, RCP 2-1, Circ. Water Pump 2 and Circ.Water Pump 4.STANDARD: Verify open indication on the breakers for RCP 1-2, RCP 2-1, Circ. Water Pump 2 and Circ. Water Pump 4.COMMENT: Trainee may not perform this step due to initial conditions.
CUE: Green Green Green Water Green Water light is LIT, Red light is OFF on HB01, breaker for RCP 2-1.light is LIT, Red light is OFF on HB03, breaker for RCP 1-2.light is LIT, Red light is OFF on HBE8, breaker for Circ.Pump 1.light is LIT, Red light is OFF on HB12, breaker for Circ.Pump 3.SAT UNSAT 19. PERFORMANCE STEP: Trip the following load breakers:
HBBD, HBBF4, HBBF2 and HBBF3.STANDARD: Verify open indication on the breakers HBBC, HBBF4, HBBF2 and HBBF3.COMMENT: Trainee may not perform this step due to initial conditions.
CUE: Green light is LIT, Red light is OFF on HBBD.Green light is LIT, Red light is OFF on HBBF4.Green light is LIT, Red light is OFF on HBBF2.Green light is LIT, Red light is OFF on HBBF3.SAT UNSAT JPM NEW 3-2 Page 19 of 21 20. PERFORMANCE STEP: Open source breaker HX02B..C.STANDARD:
Place handswitch on Cubicle 4 of Bus B (HX02B) to TRIP, and release.CUE: Handswitch HX02B has been placed in TRIP and released.
Green light LIGHTS and Red light goes OFF.SAT UNSAT 21. PERFORMANCE STEP: Turn 25SWB/LOCAL, Synchro Check Selector to the.C ........ desired source.STANDARD:
Place 25SWB/LOCAL, Synchro Check Selector to the X01 position.COMMENT: No check of synchro check relay contact position is required for dead bus transfer.CUE: 25SWB/LOCAL has been placed in the X01 position.SAT UNSAT 22. PERFORMANCE STEP: Close Source Breaker HXO1B..C.STANDARD:
Place handswitch on Cubicle 11 of Bus B (HXOTB) to CLOSE and release.CUE: Handswitch HXOlB has been placed in CLOSE and released.
RED light LIGHTS and Green light goes OFF.SAT UNSAT 23. PERFORMANCE STEP: Turn 25SWB/LOCAL, Synchro Check Selector to OFF.STANDARD:
Place 25SWB/LOCAL, Synchro Check Selector to the OFF position.CUE: 25SWB/LOCAL has been placed in the OFF position.SAT UNSAT JPM NEW 3-2 Page 20 of 21 JPM NEW 3-2 Page 20 of 21 24. PERFORMANCE STEP: Verify normal system voltage on EI 6257, B Bus Kilovolts.
STANDARD:
Observe 13.8 KV Bus B indicates approximately 13.8 KV on Cubicle 5.COMMENT: Since the Control Room is unoccupied, the examinee will either read the voltage on the local meter or ask the Shift Supervisor for guidance.
Either action is acceptable.
It is not necessary to check voltage on all three phases.CUE: No one is available to read El 6257. (If asked) The Shift Supervisor directs you to use the local indicator to check bus voltage. The phase select switch has been rotated [through all three phases] and [each phase] indicates approximately 13.8 Kilovolts.
SAT UNSAT 25. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch B Bus is in the X02 position.STANDARD:
Observe 10/LOCAL, Reserve Source Selector Switch Bus B is in the X02 position.COMMENT: Since Startup Transformer 02 will be deenergized, it is acceptable for the examinee to omit this step.CUE: (If asked) The Shift Supervisor directs you to leave the local reserve source selector switch in the X01 or X02 position.SAT UNSAT TERMINATING CUES: This JPM is complete.COMMENT: Please ensure the stool, if used, is carefully returned to its storage location and secured.END TIME JPM NEW 3 Page 21 of 21 VERIFICATION OF COMPLETION Operator SSN License: Evalu Date[ I RO [ ] SRO [ ] ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 60 Rev. 05 Page 1 of 5 TASK NO.: 001-044-04-0100 TASK DESCRIPTION:
Clearing an Asymmetry Fault K/A
 
==REFERENCE:==
 
000-003, EK3.04 (3.8/4.1), EA1.03 (3.6/3.3)
GEN.05 (3.6/3.6), GEN.06 (3.5/3.4)APPLICABLE METHOD OF TESTING: Simulate performance In-plant TIME FOR COMPLETION:
26.5 minutes APPLICABILITY:
[X] RO [XI SRO TASK STANDARDS:
Successfully clear the following alarms: 1. Annunciator alarm "CRD ASYMMETRIC ROD" is off.2. ASYMMETRY FAULT light on the rod control panel is off.REQUIRED MATERIALS:
: 1. CRD Cabinet Key (#11)2. DB-OP-02516, CRD Malfunctions Abnormal Procedure, Revision 03 GENERAL
 
==REFERENCES:==
 
DB-OP-02516, CRD Malfunctions Abnormal Procedure, Revision 03 INITIAL CONDITIONS:
The plant is operating at 78% power. Control Rod 5-3 has been dropped. It is expected to take six hours to realign the control rod. Power is being reduced to 60%.INITIATING CUES: The Shift Supervisor directs you to perform Section 1.0 of Attachment 2 of DB-OP-02516 to clear the ASYMMETRY FAULT light on the rod control panel.(Hand copy of DB-OP-02516, CRD Malfunctions, to the examinee.)
JPM No. 60 Page 2 of 5 INITIAL CONDITIONS:
The plant is operating at 78% power. Control Rod 5-3 has been dropped. It is expected to take six hours to realign the control rod. Power is being reduced to 60%.INITIATING CUES: The Shift Supervisor directs you to perform Section 1.0 of Attachment 2 of DB-OP-02516 to clear the ASYMMETRY FAULT light on the rod control panel.
JPM No. 60 Page 3 of 5 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Obtain key for control rod drive cabinets..C.STANDARD:
Obtain key for control rod drive cabinets from Control Room key cabinet.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Locate the correct Control Rod Drive Cabinet..C.STANDARD:
Locate Control Rod Drive Cabinet C4801V in Electrical Penetration Room 1.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Place the S2 asymmetry bypass switches in bypass..C.STANDARD:
Place all affected switches on the following API amps in Group 5 in the down position:
C 9, E 11, G 13, K 13, M 11, 0 09, 0 07, M 5, K 3, G 3, E 5, C 7.COMMENT: Provide CUE for appropriate S2 switch as each is placed in BYPASS by the trainee.CUE: S2 switch for Rod (_) has been placed in the DOWN (bypass)position.SAT UNSAT 4. PERFORMANCE STEP: Check the asymmetry bypass light on the rod control panel is ON.STANDARD:
Visual check at the rod control panel.CUE: The ASYMMETRY BYPASS light ON.SAT UNSAT JPM No. 60 Page 4 of 5 5. PERFORMANCE STEP: Reset the fault condition..C.STANDARD:
Depress the FAULT RESET button.CUE: FAULT RESET button has been depressed.
SAT UNSAT 6. PERFORMANCE STEP: Check the CRD asymmetric rod annunciator alarm is extinguished.
STANDARD:
Visual check that annunciator 5-2-E is off.CUE: CRD ASYMMETRIC ROD annunciator (5-2-E) is NOT LIT.SAT UNSAT 7. PERFORMANCE STEP: Check the ASYM ALARM LEDs on the PI panel for Group 5 rods are on.STANDARD:
Visual check of PI panel the Group 5 rods ASYM ALARM LEDs are ON.CUE: All Group 5 ASYM ALARM LEDs are ON.SAT UNSAT 8. PERFORMANCE STEP: Check the asymmetry fault light on the rod control panel is OFF.STANDARD:
Visual check of rod control panel that the ASYMMETRY FAULT light is OFF.CUE: The ASYMMETRY FAULT light is OFF.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 60 Page 5 of 5 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date FINAL AS-ADMINISTERED SCENARIOS FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13,1999 ES-301 Simulator Scenario Quality Checklist Form ES-301-4 Facility:
Davis-Besse Nuclear Power Station Date of Exam:9/13/1999 Scenario Numbers: 1/21 Operating Test No.: (Post NRC Review) v QUALITATIVE ATTRIBUTES Initials a b c 1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of ,tX 2'service, but it does not cue the operators into expected events. ' 1V 2. The scenarios consist mostly of related events. *YI I 3. Each event description consists of the point in the scenario when it is to be initiated the malfunction(s) that are entered to initiate the event 6 o 0 the symptoms/cues that will be visible to the crew* the expected operator actions (by shift position)* the event termination point (if applicable)
: 4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario 4 +without a credible preceding incident such as a seismic event. , 5. The events are valid with regard to physics and thermodynamics.
41 7 6. Sequencing and timing of events is reasonable, and allows the examination team to obtain complete evaluation results commensurate with the scenario objectives.
_AY 7. If time compression techniques are used, the scenario summary cleariy so indicates.
Operators have sufficient time to carry out expected activities without undue time constraints.
Cues are 41 given.8. The simulator modeling is not altered. 6 1i 9. The scenarios have been validated.
Any open simulator performance deficiencies have been Af evaluated to ensure that functional fidelity is maintained while running the planned scenarios.
l H 10. Every operator will be evaluated using at least one new or significantly modified scenario.
All 4 /other scenarios have been altered in accordance with Section D.4 of ES-301.11. All individual operator competencies can be evaluated, as verified using Form ES-301-6 (submit the form along with the simulator scenarios).
: 12. Each applicant will be significantly involved in the minimum number of transients and events specified on Form ES-301-5 (submit the form with the simulator scenarios).
: 13. The level of difficulty is appropriate to support licensing decisions for each crew position.TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO; SEE SECTION D.4.D) Actual Attnbutes
_ _1. Total malfunctions (58) 8/8 1 Y i 2. Malfunctions after EOP entry (1-2) 2 2 /3. Abnormal events (2-4) 4/ 4/4. Major transients (1-2) 2/ 2/ e 5. EOPs entered/requiring substantive actions (1-2) 1 1/ __6. EOP contingencies requiring substantive actions (0-2) 1 1 0 / e_7. Critical tasks (2-3) 3/ 3 _ Vo ES-301 Transient and Event Checklist Form ES-301-5 OPWRATI( E ST VN)O.: (hot NC eview)Aplicant Evplution Minimum Scenario Number Iypepe umber_ _ _ _ _ _ _ _1 2 _Reactivity I 1 1 Normal 1 2 2 RO Instrument 2 4, 6 4, 6 _Component 2 3, 5 3, 5 Major 1 7 8 = =Reactivity 1 Normal 0 As RO Instrument 1 Component 1 Major 1 _ = = =SRO-I Reactivity 0 = = = =Normal 1 As SRO Instrument 1 Component 1 = = = =______ ______M ajor 1 _ _ _ _ _ _ _ _ _Reactivity 0 = = = =Normal 1 SRO-U Instrument 1 Component 1 Major 1 Instructions:
(1 )(2)Author: Enter the operating test number and Form ES-D-1 event numbers for each evolution type.Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.4.d) but must be significant per Section C.2.a of Appendix D.a nt' ,i fJ 1. e Chief Examiner:
ES-301 Competencies ChecklistForm ES-301-6 (Post NRC Review)Applicant
#1 Applicant
#2 RO/SRO-I/SRO-U RO/SRO-I/SRO-U Competencies SCENARIO l SCENARIO 1 2 1 2 Understand and Interpret 1 4, 5 2, 3, 4, 2, 3, 6, 5, 6. 7, Annunciators and Alarms 5, 6, 9 7 8, 9 Diagnose Events 4, 5, 7 3, 4, 5, 3, 6, 7 4, 5, 6, and Conditions 6, 7, 9 7, 8, 9 Understand Plant 1,4, 5, 1,2, 3, 2, 3, 6, 1,4, 5, 7 4, 6, 7, 7 6, 7. 8 and System Response 7_ 4,9 6, 9 _67 Comply With and 1, 4, 5, 1, 2, 3, 2, 6, 7 1, 5, 6, Use Procedures (1) 7 4, 6, 9 7, 8 Operate Control 1, 4 5, 1, 2, 3, 2, 3, 6, 1, 5, 6, Boards (2) 7 4, 6, 9 7 7,8 Communicate and 1, 4, 5, 1, 2, 3, 1, 2, 3, 1, 5, 6, Interact With the Crew 6,7 4,6,7, 67 8 Demonstrate Supervisory Ability (3) l Comply With and Use Tech. Specs. (3)Notes: (1) Includes Technical Specification compliance for an RO.(2) Optional for an SRO-U.(3) Only applicable to SROs.Instructions:
Circle the applicant's license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
Author: ,41 , t Y s/1- A Chief Examiner:___
Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 1 Op-Test No.: 1 Examiners:
Operators:
Objectives:
The RO candidates are to (1) perform the operator actions during a Plant startup beginning at 5% power and increase power to 10% or greater. (2) implement the actions for a power range NI failing high, (3) determine the need to trip the Main Turbine due to the pilot valve on Main Stop Valve 2 fails open during Main Turbine Shell warming, (4) start Makeup Pump 2 due to an oil leak on Makeup Pump 1, (5) stop the Steam Generator 1 overfill due to Steam Generator 1 Startup Level instrument failing high, (6) trip the reactor due to a steam leak on AFPT 2, (7) establish MU/HPI cooling and (8) feed Steam Generator 2 with the Startup Feedwater Pump due to a loss of all feedwater.
Turnover:
Plant was shutdown for bushing replacement on the Main Transformer, Reactor startup is in progress and currently at -5%. Completed testing of both AFPTs for operability.
Planned: Continue Reactor startup and begin Main Turbine shell warming. In Progress:
Line-ups for placing MDFP in AFW mode, I&C changing RE600 & RE609 set point. Equipment OOS: Stator Coolant Pump B for motor replacement.
Event Malf. No. Event Event No. l Type* Description 1 Sll 1 R(RO) Continue reactor startup from about 5% to about 14%.l 2 N(BOP) Establish main turbine shell warming.3 IMF UV02C C(BOP) Fail open the internal bypass on Main Turbine Stop Valve 2 after TRUE main turbine shell warming has been started.4 IMF R3N5 100 I(RO) Fail Power Range Nuclear Instrument, N1-5, high.IMF R3N1 100 5 IMF BME5J C(RO) Oil leak on Makeup Pump 1 after the rod control panel is placed 0.5 in automatic.
6 IMF L1TL28 I(BOP) Slow failure of Steam Generator 1 Startup Level Transmitter, 0.0 LT SP9B4, to zero.7 IMF FKPBC M(AII) After Steam Generator 1 level control has been established or TRUE C(AII) the reactor trips, a steam leak on AFPT 2 develops with MS IMF SFEG 1.0 1 07A failed in the open position.IMF SFECD Loss of all feedwater due to a steam leak on AFPT 2 and AFPT 1.0 1 Governor controlling at 500 rpm.500 Motor drive feed pump breaker will not close.* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 1 & 2 Page 1 of 1 Event
 
== Description:==
 
Continue Reactor startup from about 5% to about 14%.Pstnhich mnin fiirhina shoall Worminn--aula s- Ic~i l- -u -l -solsl a 1 ll1 l Time l Position Applicant's Actions or Behavior SRO Direct a plant startup per DB-OP-06901, starting at Step 3.37-Increase reactor power to 14%.-NIP and HBP check every 5% power change.-Main turbine shell warming.-Place Main Feedwater Pump 1 in standby.RO Increase reactor power to 14% at 35 0 F/hr.-Perform a NIP and HBP check every 5% power change BOP Initiate main turbine shell warming per DB-OP-06202, Turbine Operating Procedure, Section 3.3:-Check Main Turbine inner shell temperature to determine Prewarming time.-Close the extraction steam to number 6 HPFW heaters by closing ES 2014 and ES 2015.-Close MS 2844 an MS 2845.-Close MS 2842 and 2843-Select fast on the EHC starting rate.-Adjust Load Demand to zero on the EHC panel.-Press Push for Shell Warming button on the EHC panel.-Stop all but #3 or #4 bearing lift pumps, if necessary.
-Pressurize the turbine shell to 60 psig by opening #2 Stop valve internal bypass vIv.4 .1 2 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 3 Page 1 of 1 Event
 
== Description:==
 
Fail open the internal bypass on Main Turbine Stop Valve 2 after main turbine shell warmina has been.. ..started.ETimeT Position Applicant's Actions or Behavior BOP Identify that the internal bypass on Main Stop Valve 2 has failed open:-Annunciator Alarms 14-3-F, HPT MN STM PRESS.-Increase on shell warming controls.-Increasing Main Turbine speed.BOP Determine that tripping of the main turbine is required and trip the main turbine.SRO Direct the implementation of DB-OP-02500, Turbine Trip.-Check MFW on low level limits.-Steam generator pressures are at 870 psig.BOP Verify that MFW is controlling the steam generators on low level limits BOP Verify steam generator pressure is controlling at 870 psig.I t ti I~ 1 i i j i I 1 i i I I i -i 3 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 4 Page 1 of 1 Event
 
== Description:==
 
Fail Power RanQe Nuclear Instrument, NI-5, high, Time Position Applicant's Actions or Behavior RO Identify that Power Range NI-5 has failed high.-Annunciator 5-1-H, RPS CH 2 TRIP.-Annunciator 5-2-H, RPS HI FLUX TRIP.-Power is failed high on NI N15, NI-5 Power Range indicator.
RO Perform immediate actions:-Verify < 3 power range NIs have failed.SRO Direct the implementation of DB-OP-02505, Nuclear Instrumentation Failures.-Verify immediate action.-RO to place rod control panel in manual.RO Place rod control panel in manual.Reactor power is stabilized and held constant or restored to previous level.SRO Direct placing RPS Channel 2 in bypass and NI-5 power range test module in 'Test Operate' using DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure.
BOP Place RPS channel 2 in Bypass and NI-5 Power Range Test module in 'Test Operate using DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating procedure.
SRO Direct the restoration of ICS to full automatic using DB-OP-06401, Integrated Control System Operating Procedure.
RO Return [CS to full automatic.
-Place the Rod Control Panel in Auto.SRO Refer to T.S. 3.3.1.1 for failed NI..4. 4+ 4 I1 I+ 4 I+ 4 I I+.1. L 4 4 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 5 Page 1 of 1 Event
 
== Description:==
 
Oil leak on Makeup Pump 1 after the Rod Control Panel is Place in automatic.
Time Position Applicant's Actions or Behavior RO Identify that Makeup Pump 1 has an oil leak or that Makeup Pump 1 has tripped on low oil pressure.-Annunciator Alarm 2-1-A, MU PMP 1 LUBE OIL PRESS LO.-Annunciator Alarm 6-5-C, SEAL INJ FLOW LO.-Annunciator Alarm 6-6-C, SEAL INJ TOTAL FLOW.-Makeup Pump 1 breaker indicates open, AC 105.RO Verify immediate actions of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify CCW to the RCPs (CCW pump on and associated valves open).SRO Direct the implementation of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify immediate actions.-Route to DB-OP-02512, Loss of RCS Makeup.SRO Direct the implementation of DB-OP-02512, Loss of RCS Makeup and DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Close letdown isolation valve MU 2B.-RO to close RCP Seal Injection Flow Control Valve, MU19 and Pressurizer Level Control Valve, MU 32.-RO to start the Makeup Pump 2.-RO to re-establish seal injection flow using MU 19.-RO to return Pressurizer Level Control Valve, MU 32, to automatic.
RO Close letdown isolation valve MU 2B.RO Close RCP Seal Injection Flow Control Valve, MU19 and Pressurizer Level Control Valve, MU 32.Critical Task: 022-AA1.09 3.2/3.3 RO Start Makeup Pump 2 per DB-OP-06006, Makeup and Purification System, Section 3.3.RO Return Pressurizer Level Control Valve, MU 32, to automatic.
RO Re-establish seal injection flow using MU19.SRO Refer to T.S. 3.1.2.4 for inoperable MU pump.5 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Page 1 of 1 Event
 
== Description:==
 
Slow failure of Steam Generator 1 startup level instrument, LT SP9B4, to zero.Time ] Position I Applicant's Actions or Behavior BOP Determine that Steam Generator 1 has an overfill in progress.-Annunciator 14-5-E, ICS SG 1 ON LO LVL LIMIT.-Annunciator 14-4-E, ICS INPUT MISMATCH.-Raising level on LI SP9B8A, Steam Generator I Startup Level Indicator.
SRO Direct the implementation of DB-OP-02526, Steam Generator Overfill.-BOP to place Main Feedwater Loop 1 control valves in hand.-BOP to restore Steam Generator 1's level to 40".BOP Place Main Feedwater Control Valve FW SP7B and FW SP6B, if FW 780 is open, into hand, and maintain 40" in Steam Generator 1.SRO Direct Steam Generator 1 startup level be transferred to the 'Y' instrument per DB-OP-06407, Non-Nuclear Instrumentation Operating Procedure, Section 4.1.BOP Select the 'Y' Steam Generator 1 startup level instrument per DB-OP-06407, Non-Nuclear Instrumentation Operating Procedure, Section 4.1.SRO Refer to T.S. 3.3.3.5.1 for Remote Shutdown Instrumentation.
+ 4 1* 4 t 1 1- 1-I +/-4 4 i 4 4 T t 4 4 I 4 4 I t I 4_________
________________
L __________________________________________________________________________
6 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.:* 1 Scenario No.: 1 Event No.: 7 Page 1 of 3 Event
 
== Description:==
 
After Steam Generator I level control has been established or the reactor trips a steam leak on AFPT 2 occurs with MS 107A failed in the open position.Loss of all feedwater due to steam leak on AFPT 2 and AFPT 1 governor controlling at 500 rpm.Time Position Applicant's Actions or Behavior All Identify a steam leak on AFPT 2.-Fire alarms.-Annunciator
'SG 1 TO AFPT 2 MN STM PRESS LO', 12-2-A.SRO Direct the implementation of DB-OP-02525, Steam Leaks:-BOP to attempt to isolate the leak.-RO to trip the reactor.-BOP to isolate AFW to Steam Generator 1 and open the atmospheric vent valve on Steam Generator 1.-Go to DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture.BOP Close MS 107A, SG 1 to AFPT 2.Identify that MS 1 07A failed to close.RO Trip the reactor.BOP Close AF 608, AFW to SG 1, and open Atmospheric Vent Valve 1 Critical Task: 040-AA2.01 4.2/4.7 4 4 4 I------_ _ _ _ _ I F F L I F *I 4 4 I 4 I I 4 I 7 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Page 2 of 3 Event
 
== Description:==
 
After Steam Generator 1 level control has been established or the reactor trips-a steam leak on AFPT 2 occurs with MS 1 07A failed open position.Loss of all feedwater occurs due to a steam leak on AFPT 2 and AFPT 1 governor controlling at 500 rpm.Time Position Applicant's Actions or Behavior RO Perform immediate actions:-Verify reactor power is decreasing on the intermediate range.-Verify pressurizer level is > 40Q or deenergize the pressurizer heaters.BOP Perform the immediate actions:-Verify that the turbine has tripped.SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture-Verify immediate actions.-BOP to determine the status of the motor drive feed pump.-Give Attachment 1 to the BOP to start the startup feed pump or motor driven feed pump and continue with the RO.-RO to lock both makeup pump suctions on the BWST.-RO to implement MU/HPI cooling per Attachment 4.-Route to Section 12.BOP Identify a loss of all feedwater (MFW & AF\).BOP Determine the status of the motor drive feed pump per step 4.10.4, which is unavailable due to transfer lineup being in progress and breaker will not close.RO Lock both makeup pump suctions on the BWST per step 6.2.t*I.1 +/-I-1 I 1-8 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Page 3 of 3 Event
 
== Description:==
 
After Steam Generator 1 level control has been established or the reactor trips a steam leak on AFPT 2 occurs with MS 107A failed in the ooen position.Loss of all feedwater occurs due to a steam leak on AFPT 2 and AFPT 1 governor controlling at 500 rpm.Time Position J Applicant's Actions or Behavior RO Align MU/HPI cooling per Attachment 4 (step 6.3 or Specific Rule 2).*Critical Task: E04-EK3.3 4.2/3.8-Start standby CCW pump.-*Start both HPI pumps.-*Open HP 2A through D, HPI injection valves.-*Start both LPI pumps.-*Open piggyback valves, DH63 and DH64.-*Trip all but one RCP.-Place all pressurizer heaters in off.-*Close Makeup Pump 1 to Seal Injection Valve, MU6409.-*Open Pressurizer Level Control Valve Bypass, MU6420.-Open Makeup Alternate Injection Line CTMT Isolation, MU6421.-Open Makeup Alternate Injection Valve, MU6419.-Close Makeup Pump 2 Minimum Recirc., MU6406-*Open PORV Block Valve, RC1 1.-*Lock open PORV, RC2A.-Open High Point Vent Valves, RC4608A, RC4608B, RC461OA, RC461OB, RC200 and RC239A.-Close CTMT Normal Sump Valves, DR2012A and DR2012B.-*Trip the last running RCP if subcooling margin is lost (<20 0 F SCM).BOP Align and start the startup feed pump to feed Steam Generator 2 per Attachment 1.-Have an EO align the startup feedwater pump per DB-OP-06226, Startup Feedwater Pump System Operating Procedure.
-Close the Startup Feedwater Control Valve, SP7A.-Open the Main Feedwater Stop Valve, FW601.-Block and reset the Startup Feedwater Control Valve, SP7A.-Establish
< 300 gpm to Steam Generator 2.Termination Criteria:-MU/HPI cooling established.
-Startup feedwater pump providing flow to one of the steam generator.
-Incore temperature is decreasing.
+ 44 9 of 13 Justification for Critical Tasks A. Close the RCP Seal Injection Flow Control Valve, MU 19.Failure to close the RCP Seal Injection Flow Control Valve, MU19, when Makeup Pump 2 is started will result in pressure shocking of the RCP seals. This can lead to multiple RCP seal failures and increased RCS leakage. Closing the RCP Seal Injection Flow Control Valve, MU19, will prevent RCP seal damage when Makeup Pump 2 is restarted.
B. Close AF 608, AFW to SG 1, and open Atmospheric Vent Valve 1 The steam leak on AFPT 2 steam supply line and MS 107A being failed open results in a steam leak on Steam Generator 1 that cannot be isolated.
The SFRCS System will not actuate due to the size of the reducer in the AFPT steam supply line. The operator is required to take actions to actuate SFRCS and blow down Steam Generator 1 to eliminate the potential overcooling source.C. Establish MU/HPI Cooling MU/HPI cooling is required to be established when only one makeup pump is available during a loss of all feedwater.
Establishing MU/HPI cooling will prevent the RCS pressure from exceeding the shut off head of the only makeup pump.10 of 13 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -5% power with reactor startup in progress with MFPT 2 in service.2) Verify that EHC load limiter is set at 10.3) Align valves as required per Step 3.4.4 of DB-OP-06202, Turbine Operating Procedure.
: 4) Place one of the power range Nis on a one minute video trend.5) Hang magnetic tag for stator coolant water pump B OOS.a) Place on status board that SCW Pump B is OOS for motor replacement.
: 6) Hang the chemistry sheet on the status board.7) Assign the MDFP to an EO on shift assignment board.8) Post Protected Train 1.9) Post on the Equipment status board a Tech. Spec. Status sheet for T.S. 3.1.3.6, Group 38 inoperable for Rod Insertion limits.10) Initial malfunctions.
a) Rack out Stator Coolant Pump B -IRF UJSB OPEN b) Pull the Close Power fuses on MDFP -IRF FKPBA BLOWN c) Fail open MDFP Breaker- IMF FKPBC b. Procedures
: 1) For Crew: a) DB-OP-06901, Plant Startup Procedure signed off appropriately to Step 3.37 b) DB-OP-06902, Power Operations Procedure c) DB-OP-06202, Turbine Operating Procedure signed off up to Section 3.3 d) DB-OP-06224, Main Feed Pump and Turbine Procedure with Section 3.3 signed off 11 of 13 e) DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure f) DB-OP-06401, Integrated Control System Operating Procedure g) DB-OP-06006, Makeup and Purification System Procedure h) DB-NE-03220, Imbalance, Tilt & Rod Index Cabcs -Group 38 Alarms Inoperable, with Attachment 4 completed and a time of one hour prior from current time.2) For Simulator Instructor:
a) DB-OP-06202, Turbine Operating Procedure b) DB-OP-06224, Main Feed Pump and Turbine Procedure c) DB-OP-06226, Startup Feedwater Pump System Operating Procedure c. Event Triggers 1) Activates Event 8 on a SFRCS Trip -TRGSET 8 "F3JPQ963" d. Events 1) Fail "INCREASE" button on shell warming panel ON -IOR A11A1A19S139-2 (3)ON 2) Fail "OFF" button on shell warming panel OFF -Al1lAlA19S140-2 (3) OFF 3) Fail NI 5 high -IMF R3N5 (4) 100 and IMF R3N1 (4) 100 4) Oil leak on Makeup Pump 1 -IMF BME5J (5) 0.5 5) SG 1 startup level instrument, LT SP9B4, ramp to 0 over 5 minutes -IMF L1TL28 (6) 0.0 5:00 0.16 6) Initiate AFPT steam supply line leak -IMF SFEG (7) 1.0 7) Fire alarms for AFP Room 2 -IMF KN098 (7), IMF KN101 (7), IMF KN099 (7) and IMF KN100 (7)8) Fail MS 107A open -IMF SFECD (7) 1.0 9) Fail AFPT 1 governor to 500 rpm -IMF SFEJB (8) 500 2. Cues (non-generic)
: a. Event 1 and 2 12 of 13
: 1) Report as Reactor Engineering that DB-NE-03233, Incore Instrument Channel Check, has been completed.
: 2) EO to report that low pressure turbine thermocouples are all >120'F.b. Event 3 1) I & C and Engineering sent to check out Main Stop Valve 2. Engineering will report, if pressed, that Main Stop Valve 2 is jammed in the open position.c. Event4 1) None.d. Event5 1) EO sent to the Makeup Pump Room will report oil on the floor.2) EO sent to Makeup Pump Breaker ACI 05 would report that Phase A indicates an overcurrent.
: e. Event 6 1) EO sent to AFP 2 room will report steam coming from the room vent into Turbine Building.f. Event 7 1) EO working on MDFP will report back when MDFP is aligned to the AFW mode.2) EO sent to MDFP will report that there are no indications of a problem with Breaker AD21 0.13 of 13 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/?/1999 Date: 9/?/1999 Daily Average Limits Value Limits Valuel100 02 <2 ppb 5 02 0.9 ppbl150 Cl- 4.42 ppb l20 N 2 H 4  32.9 ppb150 F- 2.35 ppb 20 SiO 2  <5 ppbl Li 2.20 ppm  3 Na <0.1 ppb pH 6.88 @ 10 Fe <10 ppb 25-50 H 2  35.8 cc/kg 5 CY 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 <100 TDG 37.8 cc/kg Measured H+Cond. 0.425 [S/cm1.0 DEI-131 1.13E-2 11Ci/gm 0.2 **"norganic H+ Cond. 0.06 RS/cm 100/E Specific Act. 0.461 jiCi/ml Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 RCi/ml **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS Tank %H 2  %02 l %N 2  Time Date WGST CWRT 1 _CWRT 2 BORON Primary to Secondary Leakage Vessel PPM Time Date RCS 1050 0830 9/?/1999 <5.0 GPD (LLD is 5.0 GPD)PZR 1055 1220 9/?/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST Based on RCS Xe-133 _ tCi/mllBAAT 1 Based on FI 1002 cfm BAAT 2 RE 1003A RE 1003B CWRT 1 5 GPD cpm cpm CWRT 2 30 GPD cpm cpm CFT 1 100 GPD cpm cpm CFT 2 ______150 GPD cpm cpm SFP Increase of Refuel Canal 60 GPD cpml' cpmt Reviewed by.Time/Date/Shift Supervisor TECH SPECSATUS Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.1.3.6 91?/1999 Rod Insertion Limits due to Verify Rod Insertion Limits at 9 Group 38 being inoperable.
least once per 4 hours.September 7, 1999 S:\OPS_GENERAL\Turnover Page I SHIFT SUPERVISOR I ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST Part 1 -Unit Status: Evolutions/
Maintenance/
Procedures DATE: 9/7/99 SHIFT: DAYS MODE: 1 5 % RTP 0 MW PROTECTED TRAIN: 1 RCS Temp: 545 OF RCS Press: 2155 psig RCS Boron: 1050 ppmB License Requirements T.S. 3.1.3.6 -Rod Index inoperable due to plant startup.Alarm Status Startup in progress.SECONDARY STATUS/CHEMISTRY PREVIOUS Tagged out Stator Cooling Water pump 2.Started line up to transfer MDFP to AFW mode.Strip chart recorder has been hooked up to LPT thermocouples.
Strip chart recorder has been hooked up for T-G excentricity due to ZR 2539 being out of service.ZONE 1 OPS BURDENS* CT1 stuck open* SA 136 Bypassing once/shift
* MT 16A & B, Sta. Air Rcvrs Moisture Trap -blowing down shiftly* MT 19 Blow down daily* SA 6446 Blowing down shiftly* SW-632 (#3 TPCW Cooler TCV) valve internals need replaced* Kaydon Lube conditioner suction line air in- leakage when placed on MFP 1* Kaydon Conditioner for the TGLO Tank removed from service due to seal leak on pump* SP7B3 Light out loose wire in socket* HD 40 stuck in a throttled position ZONE 1 WORKAROUNDS ZONE 2 OPS BURDENS* Cl/Di Bkrs removed from cubicle when racked out for > 72 hours* TE5329 failed temp element EDG #1 Rm. Vent controller in manual* MS 57, handwheel stripped -valve will not fully close* Aux Blr Feed Pump #2 bad thrust bearing, ZONE 2 WORKAROUNDS PROCEDUJRALUREOUESTED LIMITS Maintain SPE Vacuum 12-13" per Sys Eng due to MFPT seal leakage GENERAL NOTES Caustic Storage Tank -Op-16 on DR20 to prevent overflow of caustic storage tank 9-5-D Disabled (leaving room for EDG Week Tk in DOST)CCW 1 -110&deg; CCW 2 -91&deg; (controlling at 950) CCW 3 -110&deg;Hydrants 5 iso w/FP400 (leaks) -Sewage Treat plant Hydrant 20 iso w/FP526 (leaks) -DBAB Blowers on: HDP #2 O/B Mtr, HDP #1 I/B Mtr, High Voltage Switchgear Room A Phase A Isophase Bus -oil leak -Zone 2 & electrical monitoring, Required Reading, 99-003680-000 Main Transformer oil header has soaker hoses off -still installed in case of need CHEMISTRY Intake Chlorination on Bays 1 and 3 ; CW CL on timer; CW Dynacool -In Service Demin Skid in service MSR Drns -Cond.
Page 2 SHIFT SUPERVISOR
/ ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST PRIMARY STATUS/RE STATUS PREVIOUS SHIFT MWMT Release Attempted to recirc CST through its Demin UNsuccessfully ZONE 3 OPS BURDENS CST LvA Xmit -improper venting requires starting and stopping several times during Tk Pmp Dn. WO 99-1550-01 is complete.
Retest is recirc CST to leak check WC 325. Can't recirc due to WC 345 leaking.WC 345 -WC 345 leaks can not recirc CST.FI 2165 -MWMT flow indicator sticks.F1 1738 DWDT- Flow indicator sensing line tap suspected to be plugged.ZONE 3 WORK AROUNDS ZONE 3 UPDATE / RP UPDATE / SHIFT MANAGER / OUTSIDE ASSISTANT CONTROL ROOM CTRM BURDENS CTRM WORKAROUNDS SPDS -Temperature inputs CR 99-1330 CREOOS* Annunciator 2-3-D -BAAT Room Temp TI 1562 is operating irratically.
Flucuates between 1 19F and 130F.* AR 1999 -Comp pt A786 and AR 1999 failed to zero. Local boron reading & hi volt power supply look good.* CAC Overloads
-Replace Hi and Lo Speed starter overload heaters.GENERAL NOTES TM 99-0022 4 Temporary HEPA Units have been installed in CTMT- BE2175 on E21C RCS Action Level 1, Elevated RCS Activity due to fuel defect, entered 6/17/99 RCS Makeup -CWMT #1 RCP Diagnostics will not reboot WR 98-3190 Effective 8/23/99, the following card readers will be out of service for security mux work for 3 weeks: all Aux Bldg doors except the turn-style at RCA entrance, CCW Pump Rm., and Turbine Bldg entrance to SW Tunnel.PLANNED ACTIVITIES:
General: Continue plant startup.Main Turbine Chest and Shell warming.Tagging: Testing: MDFP for plant startup Followup Items I&T Changing setpoints on RE 600, RE 609, RE 5403 and RE 5405.Ops Agenda at -S:\OWC\ops databases\Ops Agenda\agenda97.mdb Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Examiners:
Scenario No.: 2 Op-Test No.: 1 Operators:
Objectives:
The RO candidates are to (1) perform a power increase beginning at 40% power to -50% or greater, (2) startup MFPT 1, (3) identify a sheared shaft on a condensate pump and start the standby condensate pump (4) control the amount of steam being release through AW 2 and TBV 2 due to the Steam Generator 2 outlet pressure instrument failure, (5) determine that a letdown cooler is leaking and isolate it, (6) determine that the reactor demand and feedwater loop demands must be placed in manual due to the T-hot instrument failure and (7) trip all RCPs for the loss of SCM due to the pressurizer code safety failing oMen.-Turnover:
Plant is currently at -40%, plans are to continue raising Dower to 50% at 5 MWe/minute and startup MFPT 1I.Equipment OOS: Makeup Pump 1 for bearing replacement and TPCW Pump 1 for PMs.I _ _ -_ _ _ _ -_ _ _ .I _ _ _ _ _ _ _ _ _ _ _ _Event Malf. No. Event Event No. Type* Description 1 R(RO) Raise power from 40% to 50%.2 N(BOP) Startup MFPT 1.3 IMF FAK40 C(BOP) Sheared shaft on Condensate Pump 1 after the startup of MFPT TRUE 1.4 IMF L1T334 I(BOP) Steam Generator 2 Outlet Pressure 'X' Instrument, PT SP12A2, 1.0 failed high.5 IMF BME1 B C(RO) Letdown Cooler 1 leaks into Component Cooling Water System 0.5 that develops over 5 minutes.6 IMF LIT6H 1.0 I(RO) Slow mid-scale failure of RCS Loop 2 T-hot instrument, TT RC3A1 after letdown has been restored.7 IMF FAAWB M(AII) After the plant has been stabilized with ICS station still in TRUE manual, Loop 1 and 2 Main Feedwater Block Valves, FW779 IMF FAB4B and FW780, fail closed.TRUE 8 IMF HV40C M(AII) Pressurizer code safety fails open on a reactor trip.TRUE 9 IMF FAAZC C(BOP) Main Feedwater Startup Control Valve, FW SP7A, fails open TRUE with SFRCS failing to automatically to actuate.IMF FA300 TRUE* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 1 & 2 Page 1 of 1 Event
 
== Description:==
 
Raise power from 40% to 50%.Startup MFPT 1.Time Position l Applicant's Actions or Behavior SRO Direct the Implementation of DB-OP-06902, Power Operations.
-RO to raise power to 50% at 5 MWe/min.-Verify all four channels of ARTS are enabled.-BOP is to startup Main Feedwater Pump 1 per DB-OP-06224, Main Feedwater Pump Operating Procedure, Section 3.6.-BOP to place the MFP 1 ICS Station in automatic per DB-OP-06401, Integrated Control System Operating Procedure.
RO Raise power to 50% at 5 MWe/min.BOP Verify all four channels of ARTS are enabled.BOP Startup Main Feedwater Pump 1 per DB-OP-06224, Main Feedwater Pump Operating Procedure, Section 3.6 starting a Step 3.6.32.-Run MFPT 1 speed up to the ICS Low Speed Stop of 3900 rpm.-Transfer MFPT 1 to ICS manual per Section 3.7.(Inform trainee that Fuse in step 3.6.36 is installed.)
BOP Place MFP 1 ICS Station in automatic per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.7.BOP Place all four channels of ARTS in operate for MFP 1.J I 4 4.9 4.1 1 4 4 I 2 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 3 Page 1 of 1 l Event
 
== Description:==
 
Sheared shaft on Condensate Pump 1 after the startup of MFPT 1.L Time I Position Applicant's Actions or Behavior BOP Identify that Condensate Pump 1 has sheared its shaft.-Low amps on Condensate Pump 1.-Annunciator 13-2-B, CNDS PMP DISCH HDR PRESS.-Indication that CD 2796, Condensate Pump Discharge Header Pressure Control l_ Valve, is not fully open.SRO Direct the startup of Condensate Pump 3 and shutdown of Condensate Pump 1.-May have the BOP place CD 420 and CD 421, Deaerator Storage Tank Level Control Valves, in hand and establish manual control over the condensate pump discharge header pressure.-BOP to start Condensate Pump 3 and shutdown Condensate Pump 1 per DB-OP-06221, Condensate System, Sections 3.5 and 3.6.BOP If directed, place CD 420 and CD 421, Deaerator Storage Tank Level Control Valves, in hand and establish manual control over the condensate pump discharge header pressure.BOP Start Condensate Pump 3 per DB-OP-06221, Condensate System, Section 3.5.BOP Stop Condensate Pump 1 per DB-OP-06221, Condensate System, Section 3.6.i I i t.f. f t i IT t I 1-i I I I 3 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 4 Page 1 of 1. l Event
 
== Description:==
 
Steam Generator 2 Outlet Pressure X' Instrument, PT SP1 2A2, failed high.Time Position Applicant's Actions or Behavior BOP/RO Identify that Steam Generator 2 outlet pressure instrument has failed high.-Annunciator 14-6-F, ICS SG 2 BTU LIMIT.-Annunciator 14-4-E, ICS INPUT MISMATCH.-Rising pressure on PI SP12A, Steam Generator 2 outlet pressure indicator.
SRO Direct the implementation of DB-OP-02014, MSR/ICS Alarm Panel 14 Annunciator.
-BOP to place Atmospheric Vent Valve 2 in hand and Loop 2 turbine bypass valves in hand per DB-OP-06401, Integrated Control System Operating Procedure, Sections 3.20 and 3.19.-May have the Loop 2 turbine bypass valves manually isolated locally.-BOP to transfer the ICS input for Steam Generator 2 outlet pressure to the Y'instrument per DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure, Section 4.1.-BOP to place Atmospheric Vent Valve 2 in automatic and Loop 2 turbine bypass valves in automatic per DB-OP-06401, Integrated Control System Operating l_ _ Procedure, Sections 3.11 and 3.10.BOP Place Atmospheric Vent Valve 2 in hand and close per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.20.BOP Place Loop 2 turbine bypass valves in hand per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.19.BOP Transfer the ICS input for Steam Generator 2 outlet pressure to the Y' instrument per DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure, Section 4.1.Critical Task: 01 5-K405 4.3/4.5 BOP Close Loop 2 turbine bypass valves.BOP Place Atmospheric Vent Valve 2 in automatic and Loop 2 turbine bypass valves in automatic per DB-OP-06401, Integrated Control System Operating Procedure, Sections 3.11 and 3.10.SRO Refer to T.S. 3.3.3.5.1 for remote shutdown instrumentation I f 4 t 4 t t t 4 I I t t I I I. t I. I 4 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 5 Page 1 of 1 l Event
 
== Description:==
 
Letdown Cooler 1 leak into Component Cooling Water System that develops over 5 minutes.Time J Position Applicant's Actions or Behavior RO Identify Letdown Cooler 1 is leaking into the CCW System.-Annunciator 11-1-A, CCW RETURN RAD HI.-Computer point P101, CC OUT LETDOWN HX PRESS.-RE 1412, CCW Line 1 Monitor, is reading higher or in alarm.SRO Direct the implementation of DB-OP-02523, Component Cooling Water System Malfunctions.
-Verify letdown is isolated.-RO to close MU 32, Pressurizer Level Control Valve.-RO to reduce the seal injection flow to minimum 3 gpm per RCP using MU 19, RCP Seal Injection Flow Control Valve, in hand.-RO to return the unaffected letdown cooler to service using DB-OP-06006, Makeup and Purification System, Section 4.16.-RO to return MU 32 to automatic.
-RO to return seal injection flow to normal using DB-OP-06006, Makeup and Purification System, Section 3.9 or DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation and place MU 19 in automatic.
RO Place MU 32, Pressurizer Level Control Valve, in hand and close the valve.RO Place MU 19, RCP Seal Injection Flow Control Valve, in hand and reduce the seal injection flow to 3 gpm per RCP.RO Return the unaffected Letdown Cooler to service by opening MU 2B Letdown Isolation Valve per DB-OP-06006, Makeup and Purification System, Section 4.16.RO Return MU 32 to automatic.
RO Return seal injection flow to normal per DB-OP-06006, Makeup and Purification System, Section 3.9 or DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation and place MU 19 in automatic.
+ I1 I1+ +J. .1.+ +.1.+ +I__ _.1. 4______ L 4________ L ______________
___________________________________________________________________
5 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 6 Page 1 of 1 Event
 
== Description:==
 
Slow mid-scale failure of RCS Loop 2 T-hot instrument, TT RC3A1.Time Position j Applicant's Actions or Behavior RO Determine RCS Loop 2 T-hot instrument is failing midscale.-Annunciator 14-4-E, ICS INPUT MISMATCH.-Annunciator 14-4-D, ICS FW LIMITED BY RX PWR.-Annunciator 4-2-B, HOT LEG TEMP HI.SRO Direct the implementation of DB-OP-06407, Non-Nuclear Instrumentation Operating Procedure:
-RO to place the reactor demand station into hand and the rod control panel into manual.-BOP to place the steam generator feedwater demand stations into hand.-Have the operators stabilize and balance the plant.RO Place the reactor demand station into hand and the rod control panel into manual.BOP Place the steam generator feedwater demand stations into hand.RO/BOP Coordinate efforts to stabilize the plant per DB-OP-06401, Integrated Control System Operating Procedure:
-Reduce RCS temperature using the Control Rod Drive system.RO/BOP Balance the primary heat production to the secondary heat removal.SRO Refer to T.S. 3.4.4 for Pressurizer Level, if necessary.
1 1 4 4 t I t t I t t I. I i i TI-I.6 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 7, 8 & 9 Page 1 of 2 Event
 
== Description:==
 
After the plant has been stabilized with ICS stations still in manual; Loop 1 and 2 Main Feedwater Block Valves. FW779 and FW780. fail closed.Pressurizer code safety fails onen on a reactor trio.Main Feedwater Startup Control Valve, FW SP7A, is failed open with SFRCS failing to automatically actuate.Time Position Applicant's Actions or Behavior RO Perform immediate actions:-Verify reactor power is decreasing on the intermediate range.-Verify pressurizer level is > 40" or deenergize the pressurizer heaters.BOP Perform the immediate actions:-Verify that the turbine has tripped.SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture-Verify immediate actions.-BOP to manually initiate and isolate SFRCS.-Have Specific Rule 1 performed when subcooling margin is lost.-RO to isolate letdown, PORV and pressurizer spray.-Route to Section 5, Lack of Subcooling Margin, of DB-OP-02000.
-Verify the RCS high point vents are isolated.-When subcooling margin recovers then route to Section 13, Solid Cooldown or Pressurizer Recovery.BOP Identify that FW SP7A has failed to close.Manually initiate and isolate SFRCS.Critical Task: EO2.EK3.3 3.6/3.4 4 4.4 4.4 4.4 4..1.-4 4.4 4.7 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 7, 8 & 9 Page 2 of 2 Event
 
== Description:==
 
After the plant has been stabilized with ICS stations still in manual, Loon 1 and 2 Main Feedwater Block Valves, FW779 and FW780, fail closed.Pressurizer code safety fails open on a reactor trip.Main Feedwater Startup Control Valve, FW SP7A, is failed open with SFRCS failing to automatically actuate.Time Position Applicant's Actions or Behavior RO Perform Specific Rule 1 when subcooling margin is lost.-Trip all running RCPs with two minutes.Critical Task: E13-EK3.4 3.5/3.7-Lock makeup pump suction valves on the BWST.-Verify standby CCW Pump starts.-Start both LPI Pumps.-Open piggyback valves, DH63 and DH64.-Open MU 6420, MU 32 bypass valve.-Verify both HPI pumps start.-Verify HP 2A through D, HPI injection valves open.RO Isolate the following:
-Letdown, by closing MU 2B.-PORV block, by closing RC 11.-Pressurizer spray block, by closing RC 10.RO Verify the RCS high point vents are isolated.Termination criteria:-Normal post trip secondary conditions on AFW.-Subcooling margin > 20 0 F.-Makeup and HPI have been throttled to maintain subcooling margin.t 4 4 4+ $4 4+ 4 4 I* 4 4 4________ I ______________
~~~~~~~~~~~I__________________________________
8 of 12 Justification for Critical Tasks A. Transfer the ICS input for Steam Generator 2 outlet pressure instrument to the 'Y' instrument.
The failed Steam Generator 2 Outlet Pressure 'X' Instrument results in the Atmospheric Vent Valve (AVV) 2 failing open and the Loop 2 Turbine Bypass Valves (TBVs) failing open. Placing the AW 2 Station into hand will close the AW 2. The Loop 2 TBVs cannot be closed unless locally isolated.
The failed instrument will cause ICS to raise reactor power to recover MWe and affect the response of secondary heat removal on a reactor trip. The response to a reactor trip would be an overcooling event. The operator selecting the Steam Generator 2 Outlet Pressure to the 'Y' instrument will close the TBVs and allow proper response of secondary heat removal.B. Manually initiate and isolate SFRCS.The Main Feedwater Startup Control Valve 2 being failed open will cause an overfill event. The overfill event in conjunction with the small break LOCA will cause an overcooling of the RCS and Steam Generator
: 2. The operator initiating and isolating the SFRCS will terminate the event.C. Trip all running RCPs within two minutes.The pressurizer code safety failing open will cause a loss of subcooling margin which requires that Specific Rule 1 be implemented.
The RCPs are required to be tripped within two minutes due to an analysis showing that the reactor core may be uncovered if the RCPs were to trip after the two minutes expired. The operator tripping the RCPs within two minutes eliminate the chance of the reactor core being uncovered.
9 of 12 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -40% power with reactor startup in progress with: a) MFPT 2 in service.b) MFPT 1 at -1000 rpm.c) Makeup Pump 2 in service.d) CCW Pump 1 in service.2) Hang "Do Not Operate" tags on Makeup Pump 1 and its oil pumps.a) Place on status board:* Makeup Pump 1 is OOS at 0600 (present date) for pump outboard bearing replacement.
* Hang T.S. sheet for Makeup Pump 1 inoperable.
: 3) Hang "Do Not Operate" tags on TPCW Pump 1.a) Place on status board that TPCW Pump 1 is OOS at 0700 (present date)for preventative maintenance.
: 4) Hang the Chemistry sheet on the status board.5) Post Protected Train 2 signs.6) Initial malfunctions.
a) Rack out Makeup Pump 1 and its oil pumps -IRF B2M1B TRUE, IRF B2M1A RACKOUT, IRF BME5A OPEN, IRF BME5D OPEN and IRF BME51 OPEN.b) Rack out TPCW Pump 1 -IRF KDP1 B REMOVE and IRF KDP1A RACKOUT c) Fails SFRCS to automatically to trip -IMF F300 10 of 12
: b. Procedures
: 1) For Crew: a) DB-OP-06901, Power Operations Procedure signed off appropriately to Step 3.6.2.b) DB-OP-06224, Main Feed Pump and Turbine Procedure signed off to Step 3.6.32.c) DB-OP-06401, Integrated Control System Operating Procedure.
d) DB-OP-06221, Condensate System Procedure.
e) DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure.
f) DB-OP-06006, Makeup and Purification System Procedure.
: 2) For Simulator Instructor:
a) DB-OP-06224, Main Feed Pump and Turbine Procedure.
: c. Event Triggers 1) Activates event 8 on a reactor trip -TRGSET 8 "LIZGlAPI(1)
< 50" d. Events 1) Shear the shaft on Condensate Pump 1 -IMF FAK40 (3)2) Fail high Steam Generator 2 Outlet Pressure Instrument, PT SP12A2 -IMF L1T334 (4) 1.0 30 0.74 3) Leak into CCW System from Letdown Cooler 1 -IMF BME1 B (5) 0.5 300 0.0 (Remove failure after letdown has isolated.)
: 4) Slow mid-scale failure of Loop 2 T-hot instrument
-IMF L1T6H (6) 0.5 10:00 0.74 5) FW 779 and FW 780 fail close -IMF FAAWB (7) and IMF FAB4B (7)6) Pressurizer code safety fails open on reactor trip -IMF HV40C (8)7) Fail open Startup Valve FW SP7A -IMF FAAZC (8)11 of 12
: 2. Cues (Non-generic)
: a. Event 1 and 2.1) Load Dispatcher reports Thunderstorm warning in Ottawa and Lucas Counties for the next two hours. A T-storm cell is located over Genoa and is moving northeast at 25 mph.b. Event 3 1) EO will report after the crew has identified the event that he heard a loud bang and found a broken coupling on Condensate Pump 1.c. Event 4 1 ) None.d. Event5 1) (Remove letdown cooler leak after letdown has isolated.).
: e. Event 6 1) None.f. Event 7, 8 & 9 1 ) None.12 of 12 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/13/1999 Date: 9/13/1999 Daily Average Limits Value Limits Value<100 02 <2 ppb <5 02 0.9 ppb<150 Cl- 4.42 ppb 220 N 2 H 4  32.9 ppb S150 F- 2.35 ppb <20 S102 <5 ppb* Li 2.20 ppm <3 Na <0.1 ppb pH 6.88 @ <10 Fe <10 ppb 25-50 H 2  35.8 cc/kg <5 Cl- 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 ,100 TDG 37.8 cc/kg Measured H+Cond. 0.425 RS/cm<1.0 DEI-131 1.13E-2 ,uCi/gm <0.2 **Inorganic H+ Cond. 0.06 uS/cm 100/E Specific Act. 0.461 ptCi/ml Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 gCi/mI **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS I Tank %H 2  %02 &deg;/&deg;N 2  Time Date W G ST _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _CWRT 1 CWRT 2 BORON Primary to Secondary Leakage Vessel PPM Time Date RCS 1020 0830 9/13/1999
<5.0 GPD (LLD is 5.0 GPD)PZR 1031 1220 9/13/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST Based on RCS Xe-133 _iCi/ml BAAT I Based on FI 1002 cfm BAAT 2 RE 1003A RE 1003B CWRT 1 l GPD cpm cpm CWRT 2 30 GPD cpm cpm CFT 1 100 GPD cpm cpm CFT 2 150 GPD cpm cpm SFP Increase of Refuel Canal 60 GPD cpmlT cpmT Reviewed by.Time/Date
/Shift Supervisor TECH PEC SATUS Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.1.2.4 9/13/1999 Makeup pump 1 due to pump Restore to operable status within 0600 outboard bearing replacement.
72 hours.Expires 9/16/1999
@ 0600 September 7, 1999 S:\OPSGENEPAL\Turnover Page I SHIFT SUPERVISOR
/ ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST Part 1 -Unit Status: Evolutions/
Maintenance!
Procedures DATE: 9/7/99 SHIFT: DAYS MODE: 1 40 % RTP 354 MW PROTECTED TRAIN: 2 RCS Temp: 582 'F RCS Press: 2155 psig RCS Boron: 1020 ppmB License Requirements T.S. 3.1.2.4 -Makeup Pump 1 due to pump outboard bearing replacement.
Alarm Status 1-5-D BUS CI BKRS NTNM due to Makeup pump 1 being racked out.1-6-D Cl/DI CONTROL PWR TRBL due to Makeup pump 1 being racked out.Plant startup in progress.SECONDARY STATUS/CHEMISTRY PREVIOUS TPCW Pump 1 out of service for PMs.Restored MDFP to AFW mode and completed all testing.ZONE 1 OPS BURDENS* CT1 stuck open* SA 136 Bypassing once/shift
* MT 16A & B, Sta. Air Rcvrs Moisture Trap -blowing down shiftly* MT 19 Blow down daily* SA 6446 Blowing down shiftly* SW-632 (#3 TPCW Cooler TCV) valve internals need replaced* Kaydon Lube conditioner suction line air in- leakage when placed on MFP 1* Kaydon Conditioner for the TGLO Tank removed from service due to seal leak on pump* SP7B3 Light out loose wire in socket* HD 40 stuck in a throttled position ZONE 1 WORKAROUNDS ZONE 2 OPS BURDENS* Ci/Dl Bkrs removed from cubicle when racked out for > 72 hours* TE5329 failed temp element EDG #1 Rm. Vent controller in manual* MS 57, handwheel stripped -valve will not fully close* Aux Blr Feed Pump #2 bad thrust bearing, ZONE 2 WORKAROUNDS PROCEDURAL/REOUESTED LIMITS Maintain SPE Vacuum 12-13" per Sys Eng due to MFPT seal leakage GENERAL NOTES Caustic Storage Tank -Op-16 on DR20 to prevent overflow of caustic storage tank 9-5-D Disabled (leaving room for EDG Week Tk in DOST)CCW 1 -91&deg; (controlling at 950) CCW 2 -1100 CCW 3 -1100 Hydrants 5 iso w/FP400 (leaks) -Sewage Treat plant Hydrant 20 iso w/FP526 (leaks) -DBAB Blowers on: HDP #2 O/B Mtr, HDP #1 I/B Mtr, High Voltage Switchgear Room A Phase A Isophase Bus -oil leak -Zone 2 & electrical monitoring, Required Reading, 99-003680-000 Main Transformer oil header has soaker hoses off -still installed in case of need CHEMISTRY Intake Chlorination on Bays 1 and 3 ; CW CL on timer; CW Dynacool -In Service Demin Skid in service MSR Drns -Cond.
Page 2 SHIFT SUPERVISOR
/ ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST PRIMARY STATUS/RE STATUS PREVIOUS SHIFT BAAT #1 Sample and testing MWMT Release SW 1357 stroke testing Filter Change and sampling RE 4597 AA Attempted to recirc CST through its Demin UNsuccessfully ZONE 3 OPS BURDENS CST LvA Xmit -improper venting requires starting and stopping several times during Tk Pmp Dn. WO 99-1550-01 is complete.
Retest is recirc CST to leak check WC 325. Can't recirc due to WC 345 leaking.WC 345 -WC 345 leaks can not recirc CST.Fl 2165 -MWMT flow indicator sticks.FI 1738 DWDT- Flow indicator sensing line tap suspected to be plugged.ZONE 3 WORK AROUNDS ZONE 3 UPDATE I RP UPDATE / SHIFT MANAGER / OUTSIDE ASSISTANT CONTROL ROOM CTRM BURDENS MU 3600, Seal Rtrn Relief- Leaks-by at 2 to 3 gph to RCDT CTRM WORKAROUNDS SPDS -Temperature inputs CR 99-1330 CREOOS* Annunciator 2-3-D -BAAT Room Temp TI 1562 is operating irratically.
Flucuates between 1 19F and 130F.* AR 1999 -Comp pt A786 and AR 1999 failed to zero. Local boron reading & hi volt power supply look good.* CAC Overloads
-Replace Hi and Lo Speed starter overload heaters.* SI 816 -AFP #2 speed indication spikes Hi with AFP #2 shutdown GENERAL NOTES TM 99-0022 4 Temporary HEPA Units have been installed in CTMT- BE2175 on E21C RCS Action Level 1, Elevated RCS Activity due to fuel defect, entered 6/17/99 RCS Makeup -CWMT #1 RCP Diagnostics will not reboot WR 98-3190 Effective 8/23/99, the following card readers will be out of service for security mux work for 3 weeks: all Aux Bldg doors except the turn-style at RCA entrance, CCW Pump Rm., and Turbine Bldg entrance to SW Tunnel.PLANNED ACTIVITIES:
General: Continue Plant startup at 5MWe/min.Place MFP 1 in service.Tagging: Testing: Continue working the fire protection valve stroke Followup Items For scheduled maintenance dates on burdens, work arounds, CREOOS or OOS RE's see WSC Management or Ops Agenda at -S:\OWC\ops databases\Ops A2enda\agenda97.mdb ES-301 Simulator Scenario Quality Checklist Form ES-301-4 Facility:
Davis-Besse Nudear Power Station Date of Exam:9/13/1 999 Scenario Numbers: 3 /4 Operating Test No.: (Post NRC Review) I QUALITATIVE ATTRIBUTES Initials a b c_1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of service, but it does not cue the operators into expected events. 0 11 2. The scenarios consist mostly of related events.3. Each event description consists of* the point in the scenario when it is to be initiated* the malfunction(s) that are entered to initiate the event* the symptoms/cues that will be visible to the crew* the expected operator actions (by shift position)* the event termination point (if applicable)
: 4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario without a credible preceding incident such as a seismic event. 7 5. The events are valid with regard to physics and thermodynamics.
__ 'f_6. Sequencing and timing of events is reasonable, and allows the examination team to obtain complete evaluation results commensurate with the scenario objectives.
: 7. If time compression techniques are used, the scenario summary dearly so indicates.
Operators have sufficient time to carry out expected activities without undue time constraints.
Cues are ,~/ I given.8. The simulator modeling is not altered.9. The scenarios have been validated.
Any open simulator performance deficiencies have been evaluated to ensure that functional fidelity is maintained while running the planned scenarios.
____10. Every operator will be evaluated using at least one new or significantly modified scenario.
All _other scenarios have been altered in accordance with Section D.4 of ES-301.11. All individual operator competencies can be evaluated, as verified using Form ES-301-6 (submit y the form along with the simulator scenarios).
/1 12. Each applicant will be significantly involved in the minimum number of transients and events _ 4f .specified on Form ES-301-5 (submit the form with the simulator scenarios).
'13. The level of difficulty is appropriate to support licensing decisions for each crew position.
,$/' _TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO; SEE SECTION D.4.D) Actual Attributes
: 1. Total malfunctions (5-8) 8 / 8 /2. Malfunctions after EOP entry (1-2) 2 / 2 / _l 3. Abnormal events (2-4) 5 / 4 / e _1 4. Major transients (1-2) 1 / 2 1 5. EOPs entered/requiring substantive actions (1-2) 0 / 2 /1 d 6. EOP contingencies requiring substantive actions (0-2) 1 / 1 7. Critical tasks (2-3) 3 1 3 /
ES-301 Transient and Event Checklist Form ES-301-5 OPERT~ING TEST NO.: (Pot NC eview)Aplicant Ey ution Minimum Scenario Number ye ypeN umber 3 4 Reactivity 1 3 2 Normal 1 1 1 RO Instrument 2 4, 6 3,5 Component 2 2, 5 4,6 Major 1 7 7 = =Reactivity 1 = = _= =Normal 0 As RO Instrument 1 Component 1 Major I SRO-I .Reactivity 0 Normal 1 As SRO Instrument 1 Component I Major 1 Reactivity 0 Normal 1 SRO-U Instrument 1 Component 1 Major I = = =Instructions:
(1)(2)Enter the operating test number and Form ES-D-1 event numbers for each evolution type.Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.4.d) but must be significant per Section C.2.a of Appendix D A, t0- p k, YO ,' te Author: Chief Examiner:>X/ T ES-301 Competencies ChecklistForm ES-301-6 (Post NRC Review)Applicant
#1 Applicant
#2 ROISRO-I/SRO-U RO/SRO-I/SRO-U Competencies SCENARIO SCENARIO 3 4 _ 3 4 _ _ _Understand and Interpret 3, 5, 6, 2, 4, 5, 2, 4, 7, 3, 6, 7, Annunciators and Alarms 7,8 6,1809, 8 Diagnose Events 3, 5, 6, 4, 5, 6, 2, 3, 4, 3, 6, 7 and Conditions 7, 8 9, 10 7, 9 Understand Plant 3, 5, 6, 1, 2, 4, 1, 2, 3, 2, 3, 6, and System Response 7, 8 5,7, 8, 4, 7, 9 7, 8,10 and___System
___Response___
9,10_ _ __ _ _ _Comply With and 3, 5, 7, 1, 2, 4, 1, 2, 3, 2, 3, 6, Use Procedures (1) 8 6,1809, 4,7,9 7,8,10 Operate Control 3, 5, 6, 1, 2, 4, 1, 2, 3, 2, 3, 6, Boards (2) 7, 8 5, 8, 9, 4, 6, 7, 7, 8,10 Boards__2 10 _ ___9 ___Communicate and 3,5, 6, 1,2,4, 1,2,3, 2,3,6, Interact With the Crew 7,8 59,68, 4,6,7, 7,8,10 Demonstrate Supervisory Ability (3)Comply With and Use Tech. Specs. (3)Notes: (1) Includes Technical Specification compliance for an RO.(2) Optional for an SRO-U.(3) Only applicable to SROs.Instructions:
Circle the applicant's license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
Author: I zli l KA ts.4 , L Chief Examiner:
Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 3 Op-Test No.: 1 Examiners:
Operators:
-Objectives:
The RO candidates are to (1) perform the Weekly T-G Overspeed Trip Mechanism Test, (2)reduce reactor power to < 80% to recover a dropped control rod in Group 7, (3) manually control both main feedwater pump turbines due to FW valve AP instrument failing high, (4) start the standby TPCW pump, (5 start Makeup Pump 2 due to Makeup Pump 1 L tripping, (6) minimize the injection of BWST inventory due to makeup tank level failing low, (7) recover an essential bus due to a loss of power and (8) actuate SFRCS at the component level.Turnover:
10 cpd tube leak on Steam Generator
: 2. Planned: Weekly T-G Overspeed Trip Mechanism Test. Equipment out of service: EDG 1 to change out contaminated lube oil, SAC 1 for PMs.Event Malf. No. Event Event No. Type* Description 1 N(BOP) Perform Weekly T-G Overspeed Trip Mechanism Test.2 IMF KDP213 C(BOP) Turbine Plant Cooling Water Pump 2 trips.TRUE 3 IMF L1lOB R(RO) Drop a control rod in Group 7 (Rod 1).TRUE 4 IMF L1TSH I(BOP) Feedwater valve AP instrument, PDT SP5B1, fails low after 0.0 Control Rod 7-1 has been recovered and ICS is full automatic.
5 IMF B2M1 I C(RO) Trip Makeup Pump 1.TRUE 6 IMF B2L1J I(RO) Both makeup tank level indicators fail low after pressurizer level TRUE control and seal injection flow have been reestablished.
IMF B2L2J TRUE 7 IMF P1ZZ M(AII) After the power reduction has been started a loss of off-site TRUE power occurs.8 IMF G528B C(RO) EDG 2 breaker trips on generator differential with a 30 second TRUE time delay.9 IMF F300 C(BOP) SFRCS fails to automatically or manually actuate.TRUE* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 1 Page 1 of 1 Event
 
== Description:==
 
Perform Weekly T-G OversDeed Trip Mechanism Test.Time Position [ Applicants Actions or Behavior SRO Direct the implementation of DB-SS-04153, Weekly T-G Overspeed Trip Mechanism Test.BOP Perform a lamp test on the EHC panel.BOP Depress LOCKED OUT on the EHC panel.BOP Depress and hold OIL TRIP, and check the MECHANICAL TRIP TRIPPED is lit on the EHC panel.BOP Release OIL TRIP on the EHC panel.BOP Depress and hold the PUSH TO RESET on the EHC panel.BOP 3 to 4 seconds after the RESET lit then release the PUSH TO RESET.BOP Check the LOCKED OUT is off, RESETTING is off and NORMAL is on.I +I +I I-A 4.I 4.2 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 2 Page 1 of 1 Event
 
== Description:==
 
Turbine Plant Cooling Water Pump 2 trips.Time Position Applicants Actions or Behavior BOP Identify that Turbine Plant Cooling Water Pump (TPCW) 2 has tripped.-Annunciator Alarm 11-1-F, TPCW Hi LVL TK LVL-TPCW Pump 2 breaker indicates open, AD 206.BOP Perform the immediate actions of DB-OP-02514, Loss of Turbine Plant Cooling Water Pump(s).-Start the standby TPCW pump.SRO Direct the Implementation of DB-OP-02514, Loss of Turbine Plant Cooling Water Pump(s).-Verify the immediate actions.-When TPCW high level tank level has been restored, return to normal operations.
1- 4 +4 +4 4.I 4.4 4-4 4.4 4.4 4 t I t I 4 4 3 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 3 Page 1 of I Event
 
== Description:==
 
Drop a control rod in Group 7 (Rod 1).Time Position Applicant's Actions or Behavior RO Identify that Control Rod 7-1 has dropped into the reactor core.-Annunciator 5-1 -E, CRD LCO-Annunciator 5-2-E, CRD ASYMMETRIC ROD-ASYM ALARM light on the Pi panel-ASYMMETRY FAULT light on rod control panel SRO Direct the implementation of DB-OP-02516, CRD Malfunctions
-RO to reduce reactor power to 60% using DB-OP-02501, Rapid Shutdown.-RO to transfer the affected control rod to the auxiliary power supply using DB-OP-06402, CRD Operating Procedure, Section 4.1.-Have the cause of dropped control rod investigated by l&C.-RO to control reactor power using DB-OP-06402, CRD Operating Procedure, Section 4.3, if necessary.
-RO to jog Control Rod 7-1 to de-energize phases to allow l&C checks.-RO to restore rod to group average per DB-OP-06402, CRD Operating Procedure.
-RO to transfer the affected control rod to the normal power supply using DB-OP-06402, CRD Operating Procedure, Section 4.2.RO Reduce reactor power to 80% or 60%.RO Transfer Control Rod 7-1 to the auxiliary power supply using DB-OP-06402, CRD Operating Procedure, section 4.1.RO Maintain reactor power using DB-OP-06402, CRD Operating Procedure, Section 4.3, if necessary.
RO Jog Control Rod 7-1 to de-energize phases to allow l&C checks.RO Restore rod to group average per DB-OP-06402, CRD Operating Procedure.
-Latch and PI reset Control Rod 7-1 per Section 4.8.-Realign Control Rod 7-1 to the group average.-Verify that reactor power does not exceed power limits.RO Transfer the affected control rod to the normal power supply using DB-OP-06402, CRD Operating Procedure, Section 4.2.4 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 4 Page 1 of 1 Event
 
== Description:==
 
Feedwater Valve AP, PDT SP5B1, fails low after Control Rod 7-1 has been recovered and ICS is full automatic.
Time l Position l Applicant's Actions or Behavior BOP Identify Feedwater Valve AP, PDT SP5B1, has failed low.-Annunciator alarm 14-4-E, ICS INPUT MISMATCH-Annunciator alarm 12-5-A, SG 1 OR 2 FW VLV AP LO-Feedwater Valve AP indicator, PDI SP5B, fails low SRO Direct the operators to perform the following:
-BOP to place both main feedwater pump ICS stations into hand per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.16.-BOP to select the "Y" valve AP instrument, PDT SP582, per DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure, Section 4.1.-BOP to place both main feedwater pump ICS station into automatic per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.7.BOP Place both main feedwater pump ICS station into hand per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.16.BOP Select the 'Y" feedwater valve AP instrument, PDT SP5B2, per DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure section 4.1.BOP Place both main feedwater pump ICS station into automatic per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.7.4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 5 Page 1 of 1 Event
 
== Description:==
 
Trip Makeup Pump 1.[ Time Position I Applicant's Actions or Behavior RO Identify that Makeup Pump 1 has tripped.-Annunciator alarm 6-5-C, SEAL INJ FLOW LO.-Annunciator alarm 6-6-C, SEAL INJ TOTAL FLOW.-Makeup Pump 1 breaker indicates open, AC 105.RO Verify immediate actions of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify CCW to the RCPs.SRO Direct the implementation of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify immediate actions.-Route to DB-OP-02512, Loss of RCS Makeup.SRO Direct the implementation of DB-OP-02512, Loss of RCS Makeup.-RO to close the Letdown Isolation Valve, MU2B.-RO to close RCP Seal Injection Flow Control Valve, MU19 and Pressurizer Level Control Valve, MU 32.-RO to start the Makeup Pump 2.-RO to re-establish seal injection flow using MU19.-RO to restore pressurizer level control to automatic using MU 32.RO Close RCP Seal Injection Flow Control Valve, MU19 and Pressurizer Level Control Valve, MU 32.Critical Task: 022-AA1.09 3.2/3.3 RO Re-establish a seal injection flow to the RCPs using MU19 per DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation.
RO Restore Pressurizer Level Control Valve, MU 32, to automatic.
4 4+ 4+ 4+ 4+ 4 4 6 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: I Scenario No.: 3 Event No.: 6 Page 1 of 1 Event
 
== Description:==
 
Both makeup tank level indicators fail low after pressurizer level control and seal injection flow have been reestablished.
Time Position Applicant's Actions or Behavior RO Identify that both makeup tank level indicators have failed low.-Annunciator alarm 2-2-C, MU TK LVL LO.-Makeup tank level indicators LR MU16 and LI MU16-2 read zero.-Makeup Pump Suction Valves, MU 3971 and MU 6405, transfer to the BWST position.SRO Direct the implementation of DB-OP-02002, Letdown/Makeup Alarm Panel 2 Annunciators:
-RO/BOP to pull fuses in the NNI cabinet.-RO restore makeup pump suction back to the makeup tank.RO/BOP Pull fuses in the NNI cabinet to fail the makeup tank transmitters to mid-scale. (Fuses are not physically modeled on the simulator thus the trainee will have to simulate there removal.)RO Transfer Makeup Pump Suction Valves, MU 3971 and MU 6405, back to the makeup tank position.+4. 1 .1.4. 4. 4.4. +A. .1.4. +4. +______ 1. .1.4. 4.4-- 4.4. + +.4. 4+ +I ___________
I ____________________________________________________
7 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 7, 8 & 9 Page 1 of 2 Event
 
== Description:==
 
After the power reduction has been started a loss of off-site power occurs.EDG 2 breaker trios on generator differential.
SFRCS fails to automatically or manually actuate.Time Position Applicant's Actions or Behavior All Identify the loss of off-site power.RO Perform immediate actions:-Verify reactor power is decreasing on the intermediate range.BOP Perform the immediate actions:-Verify that the turbine has tripped.SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture:-Verify immediate actions.-RO to verify that buses C1 and D1 are de-energized.
-Route to DB-OP-02521, Loss of AC Bus Power Sources until C1 or D1 bus re-energized.
RO Verify that buses C1 and D1 are de-energized.
SRO Direct the implementation of DB-OP-02521, Loss of AC Bus Power Sources:-BOP to verify proper SFRCS response.-RO to close Letdown CIrs. Outlet, MU3, RCP Seal Return, MU 38, and Pzr Sample Line Iso. Vlv., RC 240B.-RO to open Makeup Pump 2 breaker.-RO to re-energize buses C1 and/or D1 from the SBODG via D2 bus.-Route to Step 4.6 of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture.BOP Verify proper SFRCS response, which will require individual components to be repositioned.
-Open AFPT Steam Admission Valves, MS5889A and MS5889B-Close Main Steam Isolation Valves, MS100 and MS101.Critical Task: 061-A3.01 4.2/4.2 8 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 7, 8 & 9 Page 2 of 2 Event
 
== Description:==
 
After the power reduction has been started, a loss of off-site power occurs.EDG 2 breaker trips on generator differential.
SFRCS fails to automatically or manually actuate.Time Position [ Applicants Actions or Behavior RO Verify the following valves closed.-Close Letdown CIrs. Outlet, MU3.-RCP Seal Return, MU 38.RO Open Makeup Pump 2 breaker.RO Re-energize buses Cl and/or Dl.Critical Task: 064-A4.06 3.9/3.9 SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture, from Step 4.6:-RO to start Makeup Pump 2.-BOP to re-establish control of atmospheric vent valves.RO Start Makeup Pump 2.BOP Re-establish control of atmospheric vent valves.Termination criteria:-C1 and/or DI have been re-energized.
-Normal post trip secondary conditions on AFW.-Normal post trip primary conditions on natural circulation.
.4 .4.++4..4 +i +9 of 13 Justification for Critical Tasks A. Close the RCP Seal Injection Flow Control Valve, MU 19.Failure to close the RCP Seal Injection Flow Control Valve, MU19, when Makeup Pump 2 is started will result in pressure shocking of the RCP seals. This can lead to multiple RCP seal failure and increased RCS leakage. Closing the RCP Seal Injection Flow Control Valve, MU19, will prevent RCP seal damage when Makeup Pump 2 is restarted.
B. Establish proper SFRCS response by placing individual components in the SFRCS positions.
A failure of the SFRCS to automatically or manually actuate will result in a total loss of all feedwater.
The operator must place each SFRCS component in its SFRCS position to re-establish auxiliary feedwater cooling of the steam generators.
C. Re-energize Buses C1 and/or D1.All loss of off-site power and Buses C1 and D1 will result in a loss of RCS inventory control. Re-energizing Buses C1 and/or D1 will restore power to ECCS equipment.
10 of 13 SIMULATOR SETUP AND CUES 1. Simulator Setup a. Initial Conditions
: 1) '-100% power with summertime conditions.
: 2) Place SAC 1 control switch in lockout and hang a Red tag on the control switch.a) Place on the status board that SAC 1 is OOS for PMs.3) Hang Red tags on EDG I start pushbutton and AC101 breaker switch.a) Place on status board:* EDG 1 is OOS at three hours prior the start of the scenario for changing out contaminated lube oil.* Hang the T. S. sheet for EDG 1 inoperable.
* DB-SC-03071 is due the same time as the EDG 1 was listed as inoperable but on the next day.* DB-SC-03023 is due four hours after the start of the scenario on the present day.* DB-SC-04000 is due four hours after the start of the scenario on the present day.* DB-SC-04271 was completed seven days prior.4) Hang the chemistry sheet on the status board.5) Post Protected Train 2.6) CAEP file.a) Load the batch file -BAT TEMP\SCEN3.TXTIOO:00:0510 b) Delete dropped rod malfunction
-DMF L11OB104:00:00l1
: 7) Initial malfunctions.
a) Rack out SAC 1 -IRF KFS1A RACKOUT.b) Rack out AC01 -IRF G535A RACKOUT.c) Remove close power fuses from AC101 -IRF G535C REMOVE.1 1 of 13 d) Close EDG 1 air start motor air supply -IRF GD43 CLOSE and IRF GD44 CLOSE.e) Fail SFRCS to automatically and manually to trip -IMF F300, IMF F30AC, IMF F30BC, IMF F30CC and IMF F30DC.b. Procedures
: 1) For crew: a) DB-SS-04153, Turbine-Generator Overspeed Trip Mechanism Test with Step 3.2.2 signed off.b) DB-OP-06902, Power Operations.
c) DB-OP-06402, CRD Operating Procedure.
d) DB-OP-06401, Integrated Control System Operating Procedure.
e) DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure.
f) DB-OP-06006, Makeup and Purification System.c. Events 1)2)3)4)5)6)7)8)Trip TPCW Pump 2 -IMF KDP213 (2) TRUE.Drop Control Rod 7-1 -IMF L11OB (3).Fail Main Feedwater Valve Loop 1 AP low -IMF L1TSH (4) 0.0 30 0.44.Trip Makeup Pump 1 -IMF B2M1I (5).Both makeup tank level indicators fail low -IMF B2L1J (6) and IMF B2L2J (6).Loss of off-site power -IMF PIZZ (7).Trip EDG 2 on a generator differential
-IMF G528B (7 30)Loss of power to both makeup tank level transmitters
-IMF B2L1 L (8) and IMF B2L2L (8).12 of 13
: 2. Cues (Non-generic)
: a. Events 1 and 2 1) EO to report that breaker AD206 has a 50/51 relay actuated.2) Load Dispatcher reports Thunderstorm warning in Ottawa and Lucas Counties for the next two hours. A T-storm cell is located over Genoa and is moving northeast at 25 mph.b. Event 3 1) EO will report as necessary to support CRD operations.
: 2) I&C when sent to the CRD cabinets will report that during Group 7 movement that Phases A and B indicate blown fuses and someone has been sent to the warehouse for fuses. (Clear dropped rod malfunction using CAEP Line 2)3) I&C when told to check fuses will report that Phases BB and CC are energized and the four de-energized fuses have been checked. Fuses for Phases A and B were blown and replaced.4) I&C, when told the rod has been jogged in, will report that Phases AA and BB are energized and that remaining fuses are normal.c. Event4 1) I&C will investigate instrument failure.d. Event5 1) EO sent to the MUP Room will report an electrical smell.2) EO sent to the MUP breaker will report that Phase A indicates an overcurrent.
: e. Event 6 1) I&C or EO sent to the makeup tank level instrument will report water dribbling out of the wall around one of the instrument lines.2) (When NNI fuses are pulled for the makeup tank level transmitters, activate event 8.)f. Event 7 1 ) None.13 of 13 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/13/1999 Date: 9/13/1999 Daily Average Limits Value Limits Value<100 02 <2 ppb <5 02 0.9 ppb S150 Cl- 4.42 ppb 220 N 2 H 4  32.9 ppb<150 F 2.35 ppb 20 SiO 2  <5 ppb Li 2.20 ppm <3 Na <0.1 ppb pH 6.88 @ <10 Fe <10 ppb 25-50 H 2  35.8 cc/kg  5 Cl- 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 @<100 TDG 37.8 cc/kg Measured H+Cond. 0.425 PS/cm<1.0 DEI-131 1.13E-2 giCifgm <0.2 **Ilorganic HjCond. 0.06 AS/cm 100/E Specific Act. 0.461 gCi/ml Condensate Dissolved 02 3.2 ppb 1-131 3.67E-3 CiG/ml **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS Tank %H 2  %02 %/N 2  Time Date WGST CWRT 1 CWRT 2 BORON Primary to Secondary Leakage Vessel PPM Time Date RCS 1038 0830 9/13/1999
<5.0 GPD (LLD is 5.0 GPD)PZR 1045 1220 9/13/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST Based on RCS Xe-133 1.31E-2 ptCi/ml BAAT 1 Based on FI 1002 13 cfm BAAT2 RE 1003A RE 1003B CWRT 1 5 GPD N/A cpm N/A cpm CWRT 2 30 GPD 4.3E2 cpm 9E1 cpm CFT 1 100 GPD 1.4E3 cpm 3.0E2 cpm CFT 2 150 GPD 2.2E3 cpm 4.3E2 cpm SFP Increase of Refuel Canal 60 GPD 8.6E2 cpmt 1.4E2 cpmlT Reviewed by Shift Supervisor Time/Date/
TECH SPEC STATUS Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.8.1.1 9/13/1999 EDG 1 due to changing out of Restore to operable status within 7 1100 contaminated lube oil. days.Expires 9/20/1999
@ 1100 DB-SC-03071 due 9/14/1999
@1100 At least once per 8 hours perform DB-SC-03023 due 9/13/1999
@1800 At least once per 8 hours perform DB-SC-04000 due 9/13/1999@1800 SB-SC-04271 completed 9/7/1999.1 a September 7, 1999 S: \OPSGENERAL\Turnover Page 1 SHIFT SUPERVISOR I ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST Part 1 -Unit Status: Evolutions/
Maintenance/
Procedures DATE: 9/7/99 SHIFT: DAYS MODE: 1 100 % RTP 913 MW PROTECTED TRAIN: 2 RCS Temp: 582 'F RCS Press: 2155 psig RCS Boron: 1038 ppmB License Requirements T.S. 3.8.1.1 -EDG I due to changing out of contaminated lube oil.Alarm Status 1-1-A EDG 1 TRBL due to EDG 1 being tagged out.1-2-A EDG 1 AIR RCVR PRESS LO due to EDG 1 being tagged out.1-5-D BUS CI BKRS NTNM due to AClOl being racked out.1-6-D Cl/DI CONTROL PWR TRBL due to AClOL being racked out.SECONDARY STATUS/CHEMISTRY PREVIOUS SAC 1 out of service for PMs.ZONE 1 OPS BURDENS* CT1 stuck open* SA 136 Bypassing once/shift
* MT 16A & B, Sta. Air Rcvrs Moisture Trap -blowing down shiftly* MT 19 Blow down daily* SA 6446 Blowing down shiftly* SW-632 (#3 TPCW Cooler TCV) valve internals need replaced* Kaydon Lube conditioner suction line air in- leakage when placed on MFP 1* Kaydon Conditioner for the TGLO Tank removed from service due to seal leak on pump* SP7B3 Light out loose wire in socket* HD 40 stuck in a throttled position ZONE 1 WORKAROUNDS ZONE 2 OPS BURDENS* Cl/D1 Bkrs removed from cubicle when racked out for > 72 hours* TE5329 failed temp element EDG #1 Rin. Vent controller in manual* MS 57, handwheel stripped -valve will not fully close* Aux Blr Feed Pump #2 bad thrust bearing, ZONE 2 WORKAROUNDS PROCEDURAL/REOUESTED LIMITS Maintain SPE Vacuum 12-13" per Sys Eng due to MFPT seal leakage GENERAL NOTES Caustic Storage Tank -Op-16 on DR20 to prevent overflow of caustic storage tank 9-5-D Disabled (leaving room for EDG Week Tk in DOST)CCW 1 -1100 CCW 2 -91 0 (controlling at 950) CCW 3 -1100 Hydrants 5 iso w/FP400 (leaks) -Sewage Treat plant Hydrant 20 iso w/FP526 (leaks) -DBAB Blowers on: HDP #2 O/B Mtr, HDP #1 I/B Mtr, High Voltage Switchgear Room A Phase A Isophase Bus -oil leak -Zone 2 & electrical monitoring, Required Reading, 99-003680-000 Main Transformer oil header has soaker hoses off -still installed in case of need CHEMISTRY Intake Chlorination on Bays 1 and 3 ; CW CL on timer; CW Dynacool -In Service Demin Skid in service MSR Drns -Forward Page 2 SHIFT SUPERVISOR
/ ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST PRIMARY STATUS/RE STATUS PREVIOUS SHIFT BAAT #2 Sample and testing MWMT Release SW 1357 stroke testing RPS Ch I CTMT pressure input RPS Ch 1 Flux Delta Flux Flow is IP Filter Change and sampling RE 4597 AA Attempted to recirc CST through its Demin UNsuccessfully ZONE 3 OPS BURDENS CST LvA Xmit -improper venting requires starting and stopping several times during Tk Pmp Dn. WO 99-1550-01 is complete.
Retest is recirc CST to leak check WC 325. Can't recirc due to WC 345 leaking.WC 345 -WC 345 leaks can not recirc CST.Fl 2165 -MWMT flow indicator sticks.Fl 1738 DWDT- Flow indicator sensing line tap suspected to be plugged.ZONE 3 WORK AROUNDS ZONE 3 UPDATE / RP UPDATE I SHIFT MANAGER I OUTSIDE ASSISTANT CONTROL ROOM CTRM BURDENS MU 3600, Seal Rtrn Relief- Leaks-by at 2 to 3 gph to RCDT CTRM WORKAROUNDS SPDS -Temperature inputs CR 99-1330 CREOOS* Annunciator 2-3-D -BAAT Room Temp TI 1562 is operating irratically.
Flucuates between 1 19F and 130F.* AR 1999 -Comp pt A786 and AR 1999 failed to zero. Local boron reading & hi volt power supply look good.* CAC Overloads
-Replace Hi and Lo Speed starter overload heaters.* SI 816 -AFP #2 speed indication spikes Hi with AFP #2 shutdown GENERAL NOTES 10 gpd Steam Generator 2 Tube Leak -All actions completed for RCS Leakage Management TM 99-0022 4 Temporary HEPA Units have been installed in CTMT- BE2175 on E21C RCS Action Level 1, Elevated RCS Activity due to fuel defect, entered 6/17/99 RCS Makeup -CWMT #1 RCP Diagnostics will not reboot WR 98-3190 Effective 8/23/99, the following card readers will be out of service for security mux work for 3 weeks: all Aux Bldg doors except the turn-style at RCA entrance, CCW Pump Rm., and Turbine Bldg entrance to SW Tunnel.PLANNED ACTIVITIES:
General: Look at upgrading WO priority for Dear. 1-2 sightglass Place CST on recirc to leak check WC345 and support CST FE calibration by I&C (I/P)Tagging: Testing: DB-SS-04153, Turbine-Generator Overspeed Trip Mechanism Test.DB-SC-03070, Emergency Diesel Generator I Monthly Test (after EDG 1 is restored)DB-SC-03023, Off-site AC Bus Sources Lined Up and available.
DB-SC-04000, Station Blackout Diesel Generator Lined-up to Supply Essential Bus.Followup Items For scheduled maintenance dates on burdens, work arounds, CREOOS or OOS RE's see WSC Management or Ops Agenda at -S:\OWC\ops databases\Ons Agenda\agenda97.mdb Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Examiners:
Scenario No.: 4 Op-Test No.: 1 Operators:
Objectives:
The RO candidates are to (1) perform a transfer from four circ. water pumps operating to three circ. water pumps operating, (2) lift off of low level limits, (3) place MU 32 into hand and transfer pressurizer level to a aood instrument, (4)start SAC I due to a failure to automatically start when needed, (5) isolate letdown due to a steam generator tube leak and initiate a plant shutdown, (6) stop the steam generators from overfilling, (8) shutdown the plant using the SGTR EOP and trip the reactor (9) manually trip the main turbine, and initiate HPI/MU/PORV cooling due a steam leak in the qood steam aenerator Turnover:
1 g _pd tube leak on Steam Generator
: 2. Planned: Switch from four circ. water numns operatinq to three circ. water pumps operating for maintenance on Circ. Water Pump 4 and continue plant startup -lift off low level limits. Completed:
Maintenance on SAC 2 and returned to service, all testin of MDFP in the AFW mode .Eqluipment out of service: CCW Pump 2 for PMs and EDG 2 to change out contaminated lube oil., ......Event Malf. No. Event Event No. Type* Description 1 N(BOP) Switch from four circ. water pumps operating to three circ. water l_ pumps operating, shutdown Circ. Water Pump 4.2 R(RO) Raise reactor power from 28% to 35% to lift of low level limits.3 IMF H152C I(RO) Pressurizer level, LT RC14-2, fails low.TRUE 4 IMF KFS1G C(BOP) Station Air Compressor 2 sheared shaft with a failure of Station TRUE Air Compressor 1 to automatically start after pressurizer level IMF KFS2N control has been reestablished.
TRUE 5 IMF FATMD I(BOP) Deaerator Storage Tank 2 level, LT 420, control signal fails low.TRUE 6 IMF HH51 C(RO) Steam Generator 2 tube leak of 75 gpm builds over 10 minutes 0.015 after deaerator level has been restored to normal.7 IMF HH51 0.09 M(AII) Steam generator tube rupture of 450 gpm after a plant shutdown has been started.8 N(AII) Rapid shutdown to low level limits.1 of 16 Appendix D Scenario Outline Form ES-D-1 9 IMF L7 EHC C(BOP) Turbine fails to trip with SFRCS failing to automatically actuate.TRUE IOR Al IA1A19S1-1 OFF IMF FA300 TRUE 10 IME SA05D 0.5 C(RO) Main steam safety valve on Steam Generator 1 sticks 20% open when reactor trips.* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 1 &2 Page 1 of 1j l Event
 
== Description:==
 
Switch from four circ. water pumps operating to three circ. water pumps operating, shutdown Circ.Water Pump 4.Raise reactor power from 28% to 35% to lift off low level limits.Time Position Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-06232, Circulating Water System and Cooling Tower Operation, Section 4.12:-BOP to shutdown Circulating Water Pump 4.BOP Throttle the Discharge Valves on Circulating Water Pump 3 and 4.BOP Stop Circulating Water Pump 4 by pressing closed on the discharge valve.SRO Direct the implementation of DB-OP-06902, Power Operations:
-RO to place steam generator/reactor demand station to automatic per DB-OP-06401, Integrated Control System Operating Procedure.
-RO to lift off of low level limits.-BOP to throttle main feedwater pump flow to maintain a minimum of 3.8 MPPH.-RO/BOP to transfer Buses A and B from the startup transformer to the Aux. 11 transformer.
RO Adjust the unit load demand's rate of change to 30 MWe/min.RO Place steam generator/reactor demand station to automatic per DB-OP-06401, Integrated Control System Operating Procedure.
RO Adjust the unit load demand to raise reactor power 5% above the present value.RO Once the steam generators have lifted off low level limits then adjust unit load demand's rate of change to about 10 MWe/min.BOP Throttle the running main feedwater pump flow to maintain a minimum of 3.8 MPPH.RO Identify that control rod group 7 is at or near its out limit due to the power increase.RO Add water to the makeup tank per DB-OP-06001, Boron Concentration Control, section 3.1:-Enter the batch size, reset the totalizer and display the flow rate on the batch controller.
-Enable the batch controller by pressing run.-Open MU 40, Batch Isolation Valve, and open WC 3526, Booster System Bypass Valve.-When the water addition is complete verify MU 40, Batch Isolation Valve, closed and close WC 3526, Booster System Bypass Valve.t i Ir i i 1 1-i i i f 3 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 3 Page 1 of 1 Event
 
== Description:==
 
Pressurizer Level, LT RC14-2, fails low.Time Position [ Applicants Actions or Behavior RO Identify that pressurizer level, LT RC14-2, has failed low.-Annunciator alarm 4-1-E, PZR LO LVL HTR TRIP.-Annunciator alarm 4-2-E, PZR LVL LO.RO Perform immediate actions:-Place MU 32, Pressurizer Level Control Valve, into hand.-Adjust MU 32 demand to obtain desired flow.Critical Task: 028-AA2.10 3.3/3.4 SRO Direct the implementation of DB-OP-02513, Pressurizer System Abnormal Operation:
-Verify immediate actions.-RO to manually control RCS pressure.-RO to transfer pressurizer level to a good instrument.
-RO to place MU 32, Pressurizer Level Control Valve, into automatic.
-RO to place pressurizer heater into automatic.
RO Manually control RCS pressure using pressurizer heaters.RO Transfer pressurizer level to a good instrument.
RO Place MU 32, Pressurizer Level Control Valve, into automatic.
RO Place pressurizer heater into automatic.
I t t I. t I. t I. I.I TI TI+T 4 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 4 Page I of 1 Event
 
== Description:==
 
Station Air Compressor 2 sheared shaft with a failure of Station Air Compressor 1 to automatically start after pressurizer level control has been reestablished.
Time Position Applicant's Actions or Behavior RO/BOP Identify that Station Air Compressor 2 has tripped:-Annunciator alarm 9-3-E, STA AIR HDR PRESS LO.-Annunciator alarm 9-1-F, INST AIR HDR PRESS LO.BOP Perform immediate actions:-Verify instrument air pressure is > 75 psig.-Verify no secondary upset is in progress.SRO Direct the implementation of DB-OP-02528, Loss of Instrument Air:-Verify immediate actions.-BOP to start Station Air Compressor 1 per DB-OP-06251, Station and Instrument Air System Operation Procedure, Section 5.1.BOP Start Station Air Compressor 1 per DB-OP-06251, Station and Instrument Air System Operation Procedure.
i t 1* 1I 1-i1 I*~1 I +/-1 1-i I I I i i I t I I i .5 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 5 Page 1 of 1 Event
 
== Description:==
 
Deaerator Storage Tank 2 level, LT 420, control signal fails low.Time Position Applicant's Actions or Behavior BOP Identify that Deaerator Storage Tank 2 level, LT 420, control signal has failed low:-Annunciator alarm 13-2-B, CNDS PMP DISCH HDR PRESS.-Annunciator alarm 13-3-B, CNDS PMP SUCT PRESS LO.-Deaerator storage tank level control valve, CD 420, is fully open.SRO Direct the following:
-BOP to place deaerator storage tank level controller, LIC 420, into hand and restore deaerator storage tank level to approximately eight feet.BOP Place deaerator storage tank level controller, LIC 420, into hand.BOP Restore deaerator storage tank level to approximately eight feet using an alternate level indication.
4 1 4 I.1 I 4 1.I 4 1 4 4______ I 4 I==I 6 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: I Scenario No.: 4 Event No.: 6 Page 1 of I Event
 
== Description:==
 
Steam Generator 2 tube leak of 75 qpm builds over 10 minutes after deaerator level has been restored to normal.Time Position Applicant's Actions or Behavior ROIBOP Identify a Steam Generator 2 tube leak:-Annunciator alarm 9-4-A, VAC SYS DISCH RAD HI.-Annunciator alarm 12-1-B, MN STM LINE 2 RAD HI.-Decreasing makeup tank level with constant pressurizer level.SRO Direct the implementation of DB-OP-02531, Steam Generator Tube Leak:-RO to verify pressurizer level is being maintained.
-RO/BOP to determine that Steam Generator 2 has the tube leak.-RO to calculate leak rate.-Have Attachment 2, 3 and 4 performed.
-RO/BOP to start a plant shutdown per DB-OP-02504, Rapid Shutdown or DB-OP-06902, Power Operations.
RO Verify pressurizer level is being maintained.
RO/BOP Determine that Steam Generator 2 has the tube leak.RO Calculate leak rate using Attachment 1, Steam Generator Tube Leak Rate Calculation.
SRO Direct the implementation of DB-OP-02504, Rapid Shutdown or DB-OP-06902, Power Operations to start a plant shutdown.-RO to lower the reactor power by decreasing on the ICS unit load demand to force the plant back on to low level limits.RO Lower the reactor power by decreasing on the ICS unit load demand.t i. i I. I~1i 1 +1 +I +7 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 7 & 8 Page 1 of 2 Event
 
== Description:==
 
Steam generator tube rupture of 450 aPm after a plant shutdown has been started.Rapid shutdown to low level limits.Time Position Applicant's Actions or Behavior RO Identify that the Steam Generator 2 Tube leak rate has increased:
-Pressurizer level begins to lower.SRO Direct the implementation of DB-OP-02531, Steam Generator Tube Leak:-RO to close letdown Isolation valve, MU2B.-RO to start the second makeup pump per DB-OP-06006, Makeup and Purification System.-Route to DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Section 8.0, when the RO determines that pressurizer level is still lowering with all available makeup flow.RO Close Letdown Isolation Valve, MU2B.RO Start the second makeup pump per DB-OP-06006, Makeup and Purification System.RO Identify that pressurizer level is still lowering with all available makeup flow.J. +I. 4 4 4- I 4 i 4 4 I 4 4 I. I.I. i I. 4 I I 4 4 I I I I I 4 .1 8 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 7 & 8 Page 2 of 2 Event
 
== Description:==
 
Steam generator tube rupture of 450 qpm after a plant shutdown has been started.Rapid shutdown to low level limits.Time Position Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Section 8.0:-RO to lock makeup pump suctions on to the BWST.-RO to open CTMT Isolation for Alternate Injection Line, MU6421.-RO to control pressurizer level, > 100" if possible, using Pressurizer Level Control Valve, MU 32, and Alternate Injection Line Throttle Valve, MU6419.-RO/BOP to place the steam generator/reactor demand station into hand and reduce reactor power to low level limit if it is not already on low level limits.-Direct the auxiliary boiler to be started.-BOP to place both feedwater demands into hand and reduce them to zero.-BOP to place both turbine bypass valve controllers into hand and reduce turbine load to <50 MWe,-RO to trip the reactor.-BOP to trip the turbine.-Route to DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Step 3.2: RO Lock makeup pump suctions on to the BWST.RO Open CTMT isolation for alternate injection line, MU6421.RO Control pressurizer level, > 100" if possible, using Pressurizer Level Control Valve, MU 32, and Alternate Injection Line Throttle Valve, MU6419.RO/BOP Place the steam generator/reactor demand station into hand and reduce reactor power to low level limit if it is not already on low level limits.BOP Place both feedwater demands into hand and reduce them to zero.BOP Place both turbine bypass valve controllers into hand and reduce turbine load to < 50 MWe.RO Trip the reactor.BOP Trip the turbine.I I i I i I I i I I_________
n ________________
L __________________________________________________________________________
9 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 9&10 Page 1 of 3 Event
 
== Description:==
 
Turbine fails to trip with SFRCS failing to automatically actuate.Main steam safety valve on Steam Generator 1 is stuck open 20% when reactor trips.Time Position Applicant's Actions or Behavior RO Perform immediate actions:-Verify reactor power is decreasing on the intermediate range.-Verify pressurizer level is > 40" or deenergize the pressurizer heaters and close MU 2B, Letdown Isolation Valve.BOP Perform the immediate actions:-Identify that the turbine failed to trip.SRO Direct the BOP to trip SFRCS to initiate auxiliary feedwater and isolated the steam generators.
BOP Manually trip SFRCS to initiate auxiliary feedwater and isolated the steam generators.
Critical Task: E02-EA1.1 4.0/3.6.SRO Direct the implementation of DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Sections 3.0 and 4.0:-Verify the immediate actions.-Verify that SFRCS has been tripped to initiate auxiliary feedwater and isolated the steam generators due to the turbine failing to trip.-Route to Section 7.0 for the Overcooling.
BOP Verify proper SFRCS.-Both auxiliary feedwater pumps running and feeding the steam generators.
-Have an EO transfer AFW minimum recirculation to the CSTs.SRO Direct the implementation of DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Section 7.0:-BOP to verify that SFRCS has terminated the overcooling after SFRCS has actuated on low steam pressure in Steam Generator 1.-BOP to manually align AFW System for a low steam pressure in Steam Generator 1.-Route to Step 8.7 for the steam generator tube rupture.BOP Identify that SFRCS has failed to isolate Steam Generator 1 after SFRCS has actuated on low steam pressure in Steam Generator 1.BOP Manually align AFW System for a low steam pressure in Steam Generator 1.-Open AF3869, AFP 1 to SG 2.-Close AF3870, AFP 1 to SG 1.Critical Task: E04-EK3.3 BOP Manually align main steam to the AFW System.-Close MS1 06, Main Steam Line 1 to AFPT 1.-Close MS107A, Main Steam Line 1 to AFPT 2.BOP Manually control AVV 2 and maintain RCS temperature constant or slightly decreasing.
I +/-10 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 9 & 10 Page 2 of 3 Event
 
== Description:==
 
Turbine fails to trip with SFRCS failing to automatically actuate.Main steam safety valve on Steam Generator 1 is stuck open 20% when reactor trips.Time ] Position Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Section 8.0:-RO to place HPI in the piggyback mode.-RO to depressurize the RCS to near the subcooling margin limit to allow the makeup and HPI to recover pressurizer level.-BOP to start a cool down to 5000F,-RO/BOP to establish MU/HPI cooling.RO Place HPI in the piggyback mode.-Lock makeup pump suction on the BWST.-Start standby CCW pump.-Start both HPI pumps.-Open HP 2A through D, HPI injection valves.-Start both LPI pumps.-Open piggyback valves, DH63 and DH64.Critical Task: 035-A2.01 4.5/4.6 RO Depressurize the RCS to near the subcooling margin limit to allow the makeup and hpi to recover pressurizer level.-Turn off all pressurizer heaters.-Block SFAS if not tripped and RCS pressure is under control.-Cycle RC 2 and pressurizer heaters to reduce and maintain RCS pressure near the subcooling margin limit.-Throttle makeup and HPI to maintain pressurizer level 80" to 120".BOP Cool down to 5000F.-Throttle AW 2 to maintain RCS cooldown rate at < 1000F/hr.-If Steam Generator 2 level reaches 225" then cooldown rate limit can be increased to 235oF/hr.-At 5000F and 1000 psig in the RCS, stop the RCS cooldown.I. I 11 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 9&10 Page 3 of 3 Event
 
== Description:==
 
Turbine fails to trip with SFRCS failing to automatically actuate.Main steam safety valve on Steam Generator 1 is stuck open 20% when reactor trips.Time Position Applicant's Actions or Behavior RO/BOP Coordinate the increase pressurizer level while maintaining the RCS cooldown rate as low as possible.RO Identify that the pressurizer has gone solid:-Sudden rapid pressure increase.RO Open PORV and high point vents:-Open PORV Block Valve, RC1 1.-Lock open PORV, RC2A.-Open High Point Vent Valves, RC4608A, RC4608B, RC461 OA, RC461 OB, RC200 and RC239A.Critical Task: 035-A2.01 4.5/4.6 Termination criteria:-Cooldown in progress to 5000F.-Subcooling margin > 20OF-Makeup and HPI have been throttle to control subcooling margin.4 4 4 4 4 4 4 12 of 16 Justification for Critical Tasks A. Place Pressurizer Level Control Valve, MU32, into hand.Failure to Pressurizer Level Control Valve, MU32, into hand will result in the pressurizer filling solid.This will overpressurize the RCS. The operator must place the Pressurizer Level Control Valve, MU32, into hand and reduce makeup flow to regain control of the pressurizer level.B. Trip SFRCS to initiate auxiliary feedwater and isolate the steam generators due to the main turbine failing to trip.A failure to trip SFRCS to initiate auxiliary feedwater and isolate the steam generators when the turbine fails to trip will result in both steam generators depressurizing and a cooldown of the RCS. The excessive overcooling caused by both steam generators could result in a restart accident.
The operator must trip SFRCS to initiate auxiliary feedwater and isolate the steam generators to prevent the excessive overcooling.
C. Align AFW System due to SFRCS failing to realign AFW System on low steam pressure in Steam Generator 1.A failure to realign the AFW system to isolate Steam Generator 1 will result in excessive overcooling of the RCS. The excessive overcooling can result in exceeding the pressure and temperature limits of the RCS and restart accident.
The operator must isolate AFW to Steam Generator 1 to eliminate the overcooling.
D. Establish MU/HPI cooling.A failure to establish MU/HPI cooling will result in a loss of BWST inventory due to continued steaming of the ruptured steam generator.
The loss of the BWST inventory will result in inadequate inventory to establish long term cooling. The operator must establish MU/HPI cooling to prevent a loss of BWST inventory.
13 of 16 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -28% power with reactor startup in progress with: a) MFPT 2 in service.b) CCW Pump 3 in service for CCW Pump 2.2) Hang a Red tag on the CCW Pump 2 breaker control switch.a) Place on the status board that CCW Pump 2 is OOS at 0300 on the present day for PMs 3) Hang Red tags on EDG 2 start pushbutton and AD101 breaker switch.a) Place on status board:* EDG 2 is OOS at three hours prior to the start of the scenario for changing out contaminated lube oil.* Hang the T. S. sheet for EDG 2 inoperable
* DB-SC-03070 is due the same time as the EDG 2 was listed as inoperable, but on the next day.* DB-SC-03023 is due four hours after the start of the scenario on the present day.* DB-SC-04000 is due four hours after the start of the scenario on the present day.* DB-SC-04271 was completed seven days prior.4) Hang the Chemistry sheet on the status board.5) Post Protected Train 1.6) Place computer point H300 on a trend recorder.7) CAEP file.a) Prevent the turbine from tripping -SET "TFL7STOV=1"lI00:00:0510.
b) Load the batch file -BAT TEMP\SCEN4.TXTIOO:00:1011.
14 of 16 c) 450 gpm SGTR on SG 2 -IMF HH51 0.09104:00:0012
: 8) Initial malfunctions.
a) Rack out CCW Pump 2 -IRF KA34B REMOVE and IRF KA34A RACKOUT.b) Rack out AD101 -IRF G536C REMOVE and IRF G536A RACKOUT.c) Close EDG 2 air start motor's air supply -IRF GD45 CLOSE and IRF GD46 CLOSE.d) Prevent turbine manual trip pushbutton from tripping the turbine -IOR A11A1A19S1-1 OFF.e) Fail SFRCS to automatically to trip -IMF F300 b. Procedures
: 1) For Crew: a) DB-OP-06232, Circulating Water System and Cooling Tower Operations.
b) DB-OP-06902, Power Operations signed off up to Step 3.1.7 c) DB-OP-06401, Integrated Control System Operating Procedure.
d) DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure.
e) DB-OP-06251, Station and Instrument Air System Operating Procedure.
f) DB-OP-06001, Boron Concentration Control 2) For Simulator Instructor:
a) DB-OP-06232, Circulating Water System and Cooling Tower Operations.
: c. Event Triggers 1) Activates Event 8 on a reactor trip -TRGSET 8 "LIZG1API(1)
< 50".d. Events 1) Fail pressurizer level low -IMF H152C (3).2) Shear the shaft on SAC 2 with a failure of SAC I to auto start -IMF ? (4) and IMF KFS20 (4).15 of 16
: 3) Fail Deaerator 2 level low -IMF FATMD (5).4) 75 gpm SG 2 tube leak -IMF HH51 (6) 0.015 600 0.0 5) Fail a MSSV on SG 1 to 20% open on a reactor trip -IMF SA05D (8) 0.5.2. Cues (Non-generic)
: a. Event 1 and 2.1) EO to support the pre-brief and shutdown of Circ. Water Pump 4 as necessary.
: 2) Chem Lab will report that they have completed all necessary preparations for the shutdown of Circ. Water Pump 4.3) Load Dispatch will request a power increase rate of 10 MWe/minute as agreed to with DB management.
: 4) Load Dispatcher reports Thunderstorm warning in Ottawa and Lucas Counties for the next two hours. A T-storm cell is located over Genoa and is moving northeast at 25 mph.b. Event 3 1)c. Event4 1)I & C to investigate the instrument failure.EO sent to SAC 2 will report the compressor is running but no discharge air pressure.d. Event 5 1) I & C to investigate the instrument failure.e. Event 6 1 ) None.f. Event7&8 1 ) EO working on MDFP will report back when MDFP is aligned to the AFW mode.2) EO sent to MDFP will report that there are no indications of a problem with the breaker.g. Event 9 & 10 1) None.16 of 16 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/14/1999 Date: 9/14/1999 Daily Average Limits Value Limits Value<100 02 <2 ppb <5 02 0.9 ppb<150 C1 4.42 ppb >20 N 2 H 4  32.9 ppb<150 F- 2.35 ppb <20 SiO 2  <5 ppb* Li 2.20 ppm <3 Na <0.1 ppb pH 6.88 @ <10 Fe <10 ppb 25-50 H 2  35.8 cc/kg <5 Cl- 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 l<100 TDG 37.8 cc/kg Measured HCond. 0.425 tS/cm<1.0 DEI-131 1.13E-2 pLCi/gm 0.2 **Inorganic H+ Cond. 0.06 pS/cm 100/E Specific Act. 0.461 1iCi/ml Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 ptCi/ml **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS Tank %H 2  %02 0/%N 2  Time Date WGST CWRT 1 CWRT 2 BORON Primary to Secondary Leakage Vessel PPM Time Date RCS 1035 0830 9/14/1999
<5.0 GPD (LLD is 5.0 GPD)PZR 1051 1220 9/14/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST Based on RCS Xe-133 1.31E-2 RiCi/ml BAAT I ll Based on FI 1002 13 cfmi BAAT 2 _ _ RE 1003A RE 1003B CWRT 1 5 GPD N/A cpm N/A cpm CWRT 2 30 GPD 4.3E2 cpm 9E1 cpm CFT 1 100 GPD 1.4E3 cpm 3.0E2 cpm CFT 2 150 GPD 2.2E3 cpm 4.3E2 cpm SFP Increase of Refuel Canal 60 GPD 8.6E2 cpmT 1.4E2 cpmt Reviewed by Time/Date Shift Supervisor TECH SPECSATUS Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.8.1.1 9/14/1999 EDG 2 due to changing out of Restore to operable status within 7 contaminated lube oil. days.Expires 9/21/1999
@ ?DB-SC-03070 due 9/15/1999
@At least once per 8 hours perform DB-SC-03023 due 9/14/1999
@At least once per 8 hours perform DB-SC-04000 due 9/14/1999
@SB-SC-04271 completed 9/7/1999 September 7, 1999 S: \OPSGENERAL\Turnover Page I SHIFT SUPERVISOR
/ ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST Part 1 -Unit Status: Evolutions/
Maintenance/
Procedures DATE: 9/7/99 SHIFT: DAYS MODE: 1 27 % RTP 173 MW PROTECTED TRAIN: I RCS Temp: 582 'F RCS Press: 2155 psig RCS Boron: 1035 ppmB License Requirements T.S. 3.8.1.1 -EDG 2 due to changing out of contaminated lube oil.Alarm Status 1-1-K EDG 2 TRBL due to EDG 2 being tagged out.1-2-K EDG 2 AIR RCVR PRESS LO due to EDG 2 being tagged out.1-5-H BUS DI BKRS NTNM due to AD101 being racked out.1-6-D CI/DI CONTROL PWR TRBL due to AD101 being racked out.SECONDARY STATUS/CHEMISTRY PREVIOUS Tagged out CCW pump 2 for PMs.Returned SAC 2 to service.Completed all testing for MDFP in the AFW mode.ZONE 1 OPS BURDENS* CTI stuck open* SA 136 Bypassing once/shift
* MT 16A & B, Sta. Air Rcvrs Moisture Trap -blowing down shiftly* MT 19 Blow down daily* SA 6446 Blowing down shiftly* SW-632 (#3 TPCW Cooler TCV) valve internals need replaced* Kaydon Lube conditioner suction line air in- leakage when placed on MFP 1* Kaydon Conditioner for the TGLO Tank removed from service due to seal leak on pump* SP7B3 Light out loose wire in socket* HD 40 stuck in a throttled position ZONE 1 WORKAROUNDS ZONE 2 OPS BURDENS* C1/D1 Bkrs removed from cubicle when racked out for > 72 hours* MS 57, handwheel stripped -valve will not fully close* Aux Blr Feed Pump #2 bad thrust bearing, ZONE 2 WORKAROUNDS PROCEDURALIREOUESTED LIMITS Maintain SPE Vacuum 12-13" per Sys Eng due to MFPT seal leakage GENERAL NOTES Caustic Storage Tank -Op-16 on DR20 to prevent overflow of caustic storage tank 9-5-D Disabled (leaving room for EDG Week Tk in DOST)CCW 1 -1100 CCW 2 -1100 CCW 3 -910 (controlling at 950)Hydrants 5 iso w/FP400 (leaks) -Sewage Treat plant Hydrant 20 iso w/FP526 (leaks) -DBAB Blowers on: HDP #2 O/B Mtr, HDP #1 I/B Mtr, High Voltage Switchgear Room A Phase A Isophase Bus -oil leak -Zone 2 & electrical monitoring, Required Reading, 99-003680-000 Main Transformer oil header has soaker hoses off -still installed in case of need CHEMISTRY Intake Chlorination on Bays I and 3 ; CW CL on timer; CW Dynacool -In Service Demin Skid in service MSR Drns -Cond.
Page 2 SHIFT SUPERVISOR
/ ASSISTANT SHfIFT SUPERVISOR TURNOVER CHECKLIST PRIMARY STATUS/RE STATUS PREVIOUS SHIFT BAAT #2 Sample and testing MWMT Release SW 1357 stroke testing Attempted to recirc CST through its Demin UNsuccessfully ZONE 3 OPS BURDENS CST LAi Xmit -improper venting requires starting and stopping several times during Tk Pmp Dn. WO 99-1550-01 is complete.
Retest is recirc CST to leak check WC 325. Can't recirc due to WC 345 leaking.WC 345 -WC 345 leaks can not recirc CST.Fl 2165 -MWMT flow indicator sticks.Fl 1738 DWDT- Flow indicator sensing line tap suspected to be plugged.ZONE 3 WORK AROUNDS ZONE 3 UPDATE / RP UPDATE / SHIFT MANAGER / OUTSIDE ASSISTANT CONTROL ROOM CTRM BURDENS MU 3600, Seal Rtrn Relief -Leaks-by at 2 to 3 gph to RCDT CTRM WORKAROUNDS SPDS -Temperature inputs CR 99-1330 CREOOS* Annunciator 2-3-D -BAAT Room Temp TI 1562 is operating irratically.
Flucuates between 11 9F and 130F.* AR 1999 -Comp pt A786 and AR 1999 failed to zero. Local boron reading & hi volt power supply look good.* CAC Overloads
-Replace Hi and Lo Speed starter overload heaters.* SI 816 -AFP #2 speed indication spikes Hi with AFP #2 shutdown GENERAL NOTES 10 gpd Steam Generator 2 Tube Leak -All actions completed for RCS Leakage Management TM 99-0022 4 Temporary HEPA Units have been installed in CTMT- BE2175 on E21C RCS Action Level 1, Elevated RCS Activity due to fuel defect, entered 6/17/99 RCS Makeup -CWMT #1 RCP Diagnostics will not reboot WR 98-3190 Effective 8/23/99, the following card readers will be out of service for security mux work for 3 weeks: all Aux Bldg doors except the turn-style at RCA entrance, CCW Pump Rm., and Turbine Bldg entrance to SW Tunnel.PLANNED ACTIVITIES:
General: Shutdown Circ Water Pump 4 for Maint per DB-OP-06232, section 4.12.Continue with power increase at 10 MWe/min.Tagging: Circ Water Pump 4 for pump outboard bearing work Testing: DB-SC-0307 1, Emergency Diesel Generator 2 Monthly Test (after EDG 2 is restored)DB-SC-03023, Off-site AC Bus Sources Lined Up and available.
DB-SC-04000, Station Blackout Diesel Generator Lined-up to Supply Essential Bus.Followup Items For scheduled maintenance dates on burdens, work arounds, CREOOS or OOS RE's see WSC Management or Ops Agenda at -S:\OWC\ops databases\Ops Agenda\anenda97.mdb ES-301 Simulator Scenario Quality Checklist Form ES-301-4l Facility:Davis-Besse Nuclear Power Station Date of Exam:9/13/1999 Scenario Numbers: 5/ / Operating Test No.: (Post NRC Review)QUALITATIVE ATTRIBUTES Initials a b cl1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of 4% A service, but it does not cue the operators into expected events. S 2. The scenarios consist mostly of related events.3. Each event description consists of* the point in the scenario when it is to be initiated l the malfunction(s) that are entered to initiate the event Irk/i* the symptoms/cues that will be visible to the crew* the expected operator actions (by shift position)* the event termination point (if applicable)
: 4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario without a credible preceding incident such as a seismic event.5. The events are valid with regard to physics and thermodynamics.
: 6. Sequencing and timing of events is reasonable, and allows the examination team to obtain w v complete evaluation results commensurate with the scenario objectives.
/ A 7. If time compression techniques are used, the scenario summary dearly so indicates.
Operators
<have sufficient time to carry out expected activities without undue time constraints.
Cues are /,/'given.8. The simulator modeling is not altered. 41At 9. The scenarios have been validated.
Any open simulator performance deficiencies have been evaluated to ensure that functional fidelity is maintained while running the planned scenarios.
A 10. Every operator will be evaluated using at least one new or significantly modified scenario.
All other scenarios have been altered in accordance with Section D.4 of ES-301.11. All individual operator competencies can be evaluated, as verified using Form ES-301-6 (submit l the form along with the simulator scenarios).
: 12. Each applicant will be significantly involved in the minimum number of transients and events specified on Form ES-301-5 (submit the form with the simulator scenarios).
: 13. The level of difficulty is appropriate to support licensing decisions for each crew position.
-a TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO; SEE SECTION D.4.D) Actual Attributes
_1. Total malfunctions (5-8) 7 /2. Malfunctions after EOP entry (1-2) 2 /1 1 YA'3. Abnormal events (2-4) 4 /4. Major transients (1-2) 2 1_5. EOPs entered/requiring substantive actions (1-2) 1 I /l 6. EOP contingencies requiring substantive actions (0-2) 1 1 7. Critical tasks (2-3) 2 // __
ES-301 Competencies ChecklistForm ES-301-6 (Post NRC Review)Applicant
#1 Applicant
#2 RO/SRO-I/SRO-U RO/SRO-I/SRO-U Competencies SCENARIO SCENARIO 5 _ _5 _ _Understand and Interpret 4, 6, 7, 2, 3, 5, Annunciators and Alarms 8 7, 9 Diagnose Events 4, 6, 7, 3, 5, 7, DansEvns8 9 and Conditions Understand Plant 1,74, 6, 1, 3, 4, and System Response 7_Comply With and 1, 2, 3, 1, 3, 5, Use Procedures (1) 4,6, 7,8,9 Operate Control 1, 2, 4, 1, 3, 4, Boards '2) 5,6,7, 5,7,8 9Boards9 __2_ 9_9 Communicate and 1, 2, 4, 1, 3, 4, Interact With the Crew 5,6,7, 5,7,8, Demonstrate Supervisory Ability (3)Comply With and Use Tech. Specs. (3)Notes: (1) Includes Technical Specification compliance for an RO.(2) Optional for an SRO-U.(3) Only applicable to SROs.Instructions:
Circle the applicant's license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
Chief ES-301 Transient and Event Checklist Form ES-301-5_OPERATIN T ESTNO.: o(Pos'9t NRC R ev iew)~'Aplicant Evflu t ion Minimum Scenario Number ype ype umber 5 Reactivity 1 3 l Normal 1 2 RO Instrument 2 5,6 Component 2 2,4 = ==Major 1 7 _Reactivity 1 = = = =Normal 0 As RO Instrument 1 _ =Component 1 Major 1 = = = =SRO-1 Reactivity 0 _Normal 1 As SRO Instrument 1 = = = =Component 1 Major 1 Reactivity 0 = =Normal 1 ll SRO-U Instrument 1 ll Component 1 = = l l Major 1 l l Instructions:(1 )Enter the operating test number and Form ES-D-1 event numbers for each evolution type.(2)Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.4.d) but must be significant per Sqction C.2.a of Appendix D.Author: /4r4k Y /ow41L, Chief Appendix D Scenario Outline Form ES-D-1 Facility:
Davis Besse NPS Scenario No.: 5 Op-Test No.: .Examiners:
Operators:
Objectives:
The RO candidates are to (1) Remove High Pressure Feedwater Heater Train 1 from service, (2) reduce reactor power to 72% and trip RCP 2-2 due to an oil leak, (3) control MFPT 1 manually on the MDT 20 due to the ICS demand failing to 100%, (4) control RCS pressure manually and transfer RCS pressure NNI input due to RCS pressure failing low, (5)stabilize the plant after main steam header pressure instrument fails high, (6) trip the reactor due to a steam leak into containment, (7) deenergize Buses E2 and F2 due to an ATWS, and (8) start the motor driven feed pump due to a loss of all AFW pumps.Turnover:
Planned: Remove High Pressure Feedwater Heater Train 1 from service. Equipment out of service: CCW Pump 3 for PMs, AFW Pump 2 for outboard pump bearing replacement.
Completed:
Maintenance and testing on CAC 2 breaker.[ Event Malf. No. Event Event No. Type* Description 1 N(BOP) Remove High Pressure Feedwater Heater Train 1 from service.2 IMF HU24 0.5 C(RO) Oil leak on RCP 2-2 upper reservoir after High Pressure Feedwater Heater Train 1 is removed from service.3 R(RO) Reduce reactor power from 100% to 72% for tripping RCP 2-2.4 IMF SFR5A C(BOP) ICS demand to Main Feedwater Pump 1 fails to 100% after 5300 RCP 2-2 has been tripped and the plant is stable.5 IMF L4P2D I(RO) RCS Loop 1 pressure, PT RC2B2 fails low after manual control TRUE of MFP 1 has been established and the MFP flows are balanced.6 IMF L1T2N 1.0 I(BOP) Loop 2 main steam header pressure instrument, PT SP16A, fails l_ high after pressurizer heaters are restored to automatic control.7 IMF SAM2 0.05 M(AII) A 5% steam leak on Steam Generator 2 into containment develops after ICS control has been restore to automatic control.8 IMF L4 TRUE C(RO) An ATWS occurs that prevents CRD breakers from opening.9 IMF SFE8B C(BOP) MS 106, Steam Generator I to AFPT 1, fails to open.I TRUE l* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 1 Page 1 of 1 Event
 
== Description:==
 
Remove High Pressure Feedwater Heater Train 1 from service.Time Position Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-06229, High Pressure Feedwater Heater System Operation, starting at step 4.1.24:-Conduct a shift briefing BOP Remove high pressure feedwater heater train 1 from service:-Coordinate the closing of FW 448 with an EO while opening FW 460.-Close FW 440.+ ++ ++ +1- 1-I +I I I I 2 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 2 & 3 Page 1 of 1 Event
 
== Description:==
 
Oil leak on RCP 2-2 upper reservoir after High Pressure Feedwater Heater Train 1 is removed from service.Reduce reactor power from 100% to 72% for trimping RCP 2-2.Time Position Applicant's Actions or Behavior RO Identify that RCP 2-2 has a leak on the upper reservoir:
-Computer point, RCP 2-2 Upper Reservoir Level Low.-Annunciator Alarm 6-5-A, MONITOR SYSTEM TRBL, for high vibrations on RCP 2-2.SRO Direct the implementation of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-RO to transfer the rod control panel to automatic and reactor demand to automatic.
-RO/BOP to reduce power to 72% per DB-OP-02504, Rapid Shutdown.-RO to start RCP 2-2 lift pump and stop RCP 2-2.-BOP to verify that feedwater to the steam generators re-ratios.
-BOP to establish a zero AT-cold.-Contact l&C to verify high flux trip and flux/delta-flux/flow set points have been reduced.RO Transfer the rod control panel to automatic and reactor demand to automatic.
RO Perform power reduction to 72% using ics unit load demand or by placing steam generator/reactor demand station into hand.RO Maintain Imbalance
> -10% using axial power shaping rods.BOP Stop one of the condensate pumps when Condensate flow is < 7.0 MPPH.RO Start RCP 2-2 lift pump and stop RCP 2-2.BOP Verify that feedwater to the steam generators re-ratios.
BOP Establish a zero AT-cold by either using steam generator load ratio in hand or automatic.
3 of 12 Appendix D Operator Actions Form ES-D-2----Op-Test No.: 1 Scenario No.: 5 EventNo.:
4 Page 1 of 1 Event
 
== Description:==
 
ICS demand to Main Feedwater Pump 1 fails to 100% after RCP 2-2 has been tripped and the plant is stable.Time Position Applicant's Actions or Behavior BOP Identify that MFP 1 ICS controller has failed to the high speed stop:-Annunciator alarm 10-2-F, BFP 2 DISCH FLOW LO.-MFP 1 speed increases to 5300 rpm.SRO Direct the recovery of MFP 1:-BOP to control MFP 1 using MDT-20 controller per DB-OP-06224, Main Feedwater Pump Turbine Operating Procedure.
-BOP to balance the feedwater flow between the MFPs.BOP May place the MFP 1 ICS controller into hand and trying to reduce MFP 1 speed per DB-OP-6401, Integrated Control System Operating Procedure..
BOP Match the MDT-20 controller to the ICS controller by increasing the MDT-20 controller and place the MDT-20 controller into service.BOP Using the MDT-20 for MFP 1, reduce flow on MFP 1 until it is matched with MFP 2.4- +4- +4 4-I I-4 4-I -I-I +4 4-4 4-___________
____________________
I _____________________________________________________________________________________________
4 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 5 Page 1 of 1 Event
 
== Description:==
 
RCS Loop 1 pressure, PT RC282 fails low after manual control of MFP 1 has been established and the MFP flows are balanced.Time Position Applicant's Actions or Behavior RO Identify RCS Loop 1 pressure transmitter has failed low:-Annunciator alarm 4-4-C, HOT LEG PRESS LO.-Annunciator alarm 5-1-G, RPS CH 1 TRIP.-Annunciator alarm 5-3-G, RPS RC LO PRESS TRIP.RO Perform immediate actions.-Verify PORV is closed.-Verify pressurizer spray valve is close.SRO Direct the implementation of DB-OP-02513, Pressurizer System Abnormal Operation:
-Verify immediate actions.-RO to manually control pressurizer heaters and spray.-RO/BOP to exchange RCS pressure inputs.-RO to restore pressurizer heaters to automatic.
-RO/BOP to place RPS channel 1 in bypass.RO Manually control pressurizer heaters and spray.RO/BOP Exchange RCS pressure inputs per DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure, Section 4.3 RO Restore pressurizer heaters to automatic.
RO/BOP Place RPS channel 1 in bypass using DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure, Section 4.5.~1- +-t1* +f+i i i i i i I -I 5 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: I Scenario No.: 5 Event No.: 6 Page 1 of I Event
 
== Description:==
 
Loop 2 main steam header pressure instrument, PT SP1 6A, slowly fails high after pressurizer heaters are restored to automatic control.Time ] Position Applicant's Actions or Behavior BOP Identify that loop 2 main steam header pressure instrument has failed high.-Annunciator alarm 14-3-F, HPT MN STM PRESS.-Annunciator alarm 14-4-E, ICS INPUT MISMATCH-Increasing MWe.SRO Direct the implementation of DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure:
-BOP to place main turbine into manual and turbine bypass valves into manual, and recover main steam header pressure.-RO to place Steam Generator/Reactor Demand to hand to prevent a power reduction.
-BOP to transfer main steam header pressure input to the Y instrument.
BOP Place the main turbine in manual and reduce main turbine load to recover main steam header pressure.RO Place Steam Generator/Reactor Demand Station into manual BOP Place turbine bypass valves into manual and close them.BOP Transfer main steam header pressure input to the Y instrument, PT SP1 6B.SRO Direct the implementation of DB-OP-06401, Integrated Control System Operating Procedure:
-BOP to restore main turbine to automatic-BOP to restore turbine bypass valves to automatic.
BOP Restore main turbine to automatic.
BOP Restore turbine bypass valves to automatic.
I 1 1- 1-I I I 6 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 7, 8 & 9 Page 1 of 3 Event
 
== Description:==
 
A 5% Steam Leak on Steam Generator 2 into Containment after ICS has been restored to automatic control.ATWS that prevents CRD breakers from opening.MS 106. Steam Generator I to AFPT 1, fails to open.[ Time Position Applicant's Actions or Behavior RO/BOP Identify the steam leak, into containment, on Steam Generator 2:-Annunciator alarm 4-4-A, CTMT TO ANNULUS AP HI/LO.-Annunciator alarm 4-3-A, CTMT NORM SUMP LVL HI.-Annunciator alarm 14-3-F, HPT MN STM PRESS.-Mismatch between MWe generated and reactor power.-Annunciator alarm 5-1-B, SFAS CTMT PRESS >18.4 PSIA CH TRIP.SRO Direct the implementation the Immediate Actions of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture, due to alarm 5-1-B:-RO to trip the reactor.-BOP to trip the turbine.RO Trip the reactor.BOP Trip the turbine.RO Identify that the reactor failed to trip:-Control rods fail to insert.-No annunciator alarm 8-1-A, CRD TRIP CONFIRM.SRO Direct the RO to de-energize and re-energize Buses E2 and F2.RO De-energize and re-energize Buses E2 and F2 and confirm control rods have inserted into the core.Critical Task: 029-EA1.1 1 3.9/4.1 I*1 4. 4.1 1-1 I I 4 .1 I I 4 .1 I 4 7 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 7. 8 & 9 Page 2 of 3 Event
 
== Description:==
 
A 5% steam leak on Steam Generator 2 into containment after the Pressurizer heaters have been restored to automatic.
ATWS that prevent CRD breakers from opening.MS 106, Steam Generator 1 to AFPT 1, fails to open.Time Position l Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture:-BOP to stop all but one condensate pump.-RO to transfer makeup pump suctions to the BWST and start the second makeup pump.-BOP to start the motor drive feedwater pump and feed Steam Generator 1.-Route to Section 7.0, Overcooling, of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture.BOP Stop all but one condensate pump.RO Transfer makeup pump suctions to the BWST.RO Start the second makeup pump.BOP Start the motor drive feedwater pump and feed Steam Generator 1.Critical Task: B&W E02.EA1.1 4.013.6-Enable both MDFP discharge valves and verify they are closed.-Start the MDFP.-Using the MDFP discharge valve to Steam Generator 1 establish flow.-Establish a level of about 49" in Steam Generator 1.4. 4i. +1- +4. +8 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 7, 8 & 9 Page 3 of 3 Event
 
== Description:==
 
A 5% steam leak on Steam Generator 2 into Containment after the pressurizer heaters have been restored to automatic.
ATWS that Prevent CRD breakers from opening.MS 106, Steam Generator I to AFPT 1. fails to open.Time Position Applicant's Actions or Behavior SRO Direct the implementation of Section 7.0, Overcooling, of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture:-RO/BOP to verify that the overcooling has terminated.
-BOP to take manual control of Steam Generator 1 AVV.-RO to depressurize the RCS to near the subcooling margin limit.-RO to borate the RCS.-BOP to maintain steam generator tube to shell differental temperature within limits.ROIBOP Verify that the overcooling has terminated.
BOP Take manual control of Steam Generator 1 AW.-Place AVV 1 into manual.-Block the SFRCS to AW 1 and depress auto.-Maintain RCS temperature constant or slightly decreasing.
RO Depressurize the RCS to near the subcooling margin limit.-Turn off all pressurizer heaters.-Cycle the pressurizer spray to reduce SCM to near the limit.-Block SFAS if RCS pressure under control.RO Borate the RCS.BOP Maintain steam generator tube to shell differential temperature within limits using AVV 1.Termination criteria:-Subcooling margin is being maintained near the limit.-RCS temperature is being maintained within the steam generator tube to shell differential temperature limit.-About 49" is being maintained in Steam Generator 1.t+ 4 I-4. 4 I-4+ 4 9 of 12 Justification for Critical Tasks A. De-energizing Buses E2 and F2.Failure to de-energizing Buses E2 and F2 will result in overheating of the RCS and reactor core. The overheating could cause the RCS to rupture or damage to the reactor core. The operator must de-energizing Buses E2 and F2 to get the control rods to drop into the reactor core.B. Start the motor drive feedwater pump and establishing feed flow to Steam Generator 1.A failure to start the motor driven feedwater pump and establishing feed flow to Steam Generator 1 will result in overheating of the RCS. The overheating of the RCS could cause damage to the reactor core.The operator must start the motor driven feedwater pump and establishing feed flow to Steam Generator 1 to stop the RCS from overheating.
10 of 12 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -92 power, middle of life.2) Hang Red tags on both of CCW Pump 3 breaker switches.a) Enter on the status board that CCW Pump 3 is OOS for motor PMs.3) Hang Red tags on AF 3872, AF 3871, MS 107, MS 107A and AFPT 2 Governor Controller.
a) Enter on the status board: AFP 2 is OOS at 0600 on the present day for pump outboard bearing replacement.
* Hang T.S. sheet for AFP 2 inoperable.
: 4) Hang the Chemistry sheet on the Status board. Hang the Chemistry sheet on the status board.5) Post Protected Train 1.6) Initial malfunctions.
a) Prevent the reactor from tripping -IMF L4, IMF L8, IMF L5D2 and IMF L5D1.b) Fail MS line 1 to AFPT 1, MS 106 closed -IMF SFE8B.c) Tag out AFP 2 -IMF FKGFB, IMF SFECB, IRF FKGF FALSE, IRF FKGE FALSE, IRF SFECA OPEN and IRF SFE6A OPEN.b. Procedures
: 1) F For crew: a) DB-OP-06229, High Pressure Feedwater Heater System Operation, signed off up to and including step 4.1.23.b) DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure.
c) DB-OP-06401, Integrated Control System Operating Procedure.
11 of 12 d) DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure.
: c. Events 1) RCP 2-2 upper reservoir leak -IMF HU24 (2) 0.5.2) ICS demand to MFPT 1 fail to 100% -IMF SFR5A (4) 5300.3) Fail RCS Loop 1 pressure low -IMF L4P2D (5).4) Fail Loop 2 main steam header pressure transmitter high -IMF L1T2N (6) 1.0 300 0.45 5) 5% steam leak on SG 2 into CTMT -IMF SAM2 (7) 0.05 2. Cues (Non-generic)
: a. Event 1.1) Role play as EO to support shutdown of Circulating Water Pump 4.b. Event 2.1) None.c. Event 3 1 ) Role play as EO, as necessary, to support power reduction.
: d. Event4 1) I&C and System Engineering to trouble shoot MFPT 1 problem.e. Event 5 1) I&C and System Engineering to trouble shoot RPS Ch. 1 RCS pressure transmitter.
: f. Event 6 1) I&C and System Engineering to trouble Loop 2 main steam header pressure transmitter.
: g. Event 7, 8 & 9 1) EO sent to check MS 106 will report that the valve is jammed closed.12 of 12 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/14/1999 Date: 9/14/1999 Daily Average Limits Value Limits Value<100 02 <2 ppb <5 02 0.9 ppb<150 Cl- 4.42 ppb >20 N 2 H 4  32.9 ppb150 F- 2.35 ppb <20 SiO 2  <5 ppb* Li 2.20 ppm <3 Na <0.1 ppb pH 6.88 @ <10 Fe <10 ppb 25-50 H 2  35.8 cc/kg <5 Cl- 0.07 ppb N 2  1.97 cc/kg >9.3 pH 9.82 (<100 TDG 37.8 cc/kg Measured H+Cond. 0.425 MS/cm S1.0 DEI-131 1.13E-2 ptCi/gm <0.2 **Inorganic H+ Cond. 0.06 MS/cm 100/E Specific Act. 0.461 piCi/ml Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 iLCi/ml **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS _Tank %H 2  %02 _ /_N_ Time Date W GST __ _ _ _ __ _ _ _CWRT 1 CWRT 2 BORON Primary to Secondary Leakage Vessel PPM Time Date RCS 1038 0830 9/14/1999
<5.0 GPD (LLD is 5.0 GPD)PZR 1051 1220 9/14/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST Based on RCS Xe-133 ilCi/ml BAAT I Based on FI 1002 cfmi lBAAT 2 RE 1003A RE 1003B CWRT 1 5 GPD cpm cpm CWRT 2 30 GPD cpm cpm CFT 1 100 GPD cpm cpm CFT 2 150 GPD cpm cpm SFP Increase of Refuel Canal 60 GPD cpmT_ cpmlr Reviewed by Shift Supervisor Time/Date/
TECH SPEC STATUS Tech Date/Time Action Required/When Spec Entered E uipName/Reason Remarks 3.7.1.2 9/14/1999 AFP 2 due to replacement of Restore to operable status within 0600 pump outboard bearing 72 hours.Expires 9/17/1999
@ 0600 September 7, 1999 5 :\ OPS_4;GENERA L\ Turnover Page 1 SHIFT SUPERVISOR
/ ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST Part 1 -Unit Status: Evolutions/
Maintenance/
Procedures DATE: 9/7/99 SHIFT: DAYS MODE: 1 92 % RTP 782 MW PROTECTED TRAIN: 1 RCS Temp: 582 'F RCS Press: 2155 psig RCS Boron: 1038 ppmB License Requirements T.S. 3.7.1.2 -AFP 2 due to replacement of pump outboard bearing Alarm Status 10-4-H AFP 2 TRBL, due to AFP 2 being tagged out.10-5-H AFP 2 SUCT PRESS LO, due to AFP 2 being tagged out.SECONDARY STATUSICHEMISTRY PREVIOUS Tagged out AFP 2 Tagged ou CCW pump 3 for motor PMs Isolated extraction steam to HP FW Htr train 1.ZONE 1 OPS BURDENS* CTI stuck open* SA 136 Bypassing once/shift
* MT 16A & B, Sta. Air Rcvrs Moisture Trap -blowing down shiftly* MT 19 Blow down daily* SA 6446 Blowing down shiftly* SW-632 (#3 TPCW Cooler TCV) valve internals need replaced* Kaydon Lube conditioner suction line air in- leakage when placed on MFP 1* Kaydon Conditioner for the TGLO Tank removed from service due to seal leak on pump* SP7B3 Light out loose wire in socket* HD 40 stuck in a throttled position ZONE 1 WORKAROUNDS ZONE 2 OPS BURDENS* Cl/Dl Bkrs removed from cubicle when racked out for > 72 hours* TE5329 failed temp element EDG #1 Rm. Vent controller in manual* MS 57, handwheel stripped -valve will not fully close* Aux Blr Feed Pump #2 bad thrust bearing, ZONE 2 WORKAROUNDS PROCEDURAL/REQUESTED LIMITS Maintain SPE Vacuum 12-13" per Sys Eng due to MFPT seal leakage GENERAL NOTES Caustic Storage Tank -Op- 16 on DR20 to prevent overflow of caustic storage tank 9-5-D Disabled (leaving room for EDG Week Tk in DOST)CCW 1 -110&deg; CCW 2 -910 (controlling at 950) CCW 3 -1100 Hydrants 5 iso w/FP400 (leaks) -Sewage Treat plant Hydrant 20 iso w/FP526 (leaks) -DBAB Blowers on: HDP #2 O/B Mtr, HDP #1 I/B Mtr, High Voltage Switchgear Room A Phase A Isophase Bus -oil leak -Zone 2 & electrical monitoring, Required Reading, 99-003680-000 Main Transformer oil header has soaker hoses off -still installed in case of need CHEMISTRY Intake Chlorination on Bays 1 and 3 ; CW CL on timer; CW Dynacool -In Service Demin Skid in service MSR Drns -Forward Page 2 SHIFT SUPERVISOR
/ ASSISTANT SHIFT SUPERVISOR TURNOVER CHECKLIST PRIMARY STATUS/RE STATUS PREVIOUS SHIFT BAAT #2 Sample and testing MWMT Release SW 1357 stroke testing RPS Ch 2 CTMT pressure input RPS Ch 2 Flux Delta Flux Flow is IP Filter Change and sampling RE 4597 AA Attempted to recirc CST through its Demin UNsuccessfully ZONE 3 OPS BURDENS CST LvA Xmit -improper venting requires starting and stopping several times during Tk Pmp Dn. WO 99-1550-01 is complete.
Retest is recirc CST to leak check WC 325. Can't recirc due to WC 345 leaking.WC 345 -WC 345 leaks can not recirc CST.FI 2165 -MWMT flow indicator sticks.Fl 1738 DWDT- Flow indicator sensing line tap suspected to be plugged.ZONE 3 WORK AROUNDS ZONE 3 UPDATE / RP UPDATE / SHIFT MANAGER / OUTSIDE ASSISTANT CONTROL ROOM CTRM BURDENS MU 3600, Seal Rtrn Relief- Leaks-by at 2 to 3 gph to RCDT CTRM WORKAROUNDS SPDS -Temperature inputs CR 99-1330 CRE0OS* Annunciator 2-3-D -BAAT Room Temp TI 1562 is operating irratically.
Flucuates between 1 19F and 130F.* AR 1999 -Comp pt A786 and AR 1999 failed to zero. Local boron reading & hi volt power supply look good.* SI 816 -AFP #2 speed indication spikes Hi with AFP #2 shutdown GENERAL NOTES TM 99-0022 4 Temporary HEPA Units have been installed in CTMT- BE2175 on E21C RCS Action Level 1, Elevated RCS Activity due to fuel defect, entered 6/17/99 RCS Makeup -CWMT #1 RCP Diagnostics will not reboot WR 98-3190 Effective 8/23/99, the following card readers will be out of service for security mux work for 3 weeks: all Aux Bldg doors except the turn-style at RCA entrance, CCW Pump Rm., and Turbine Bldg entrance to SW Tunnel.PLANNED ACTIVITIES:
General: Remove HP FW Htr Train 1 from service due to tube failures. (Will repair during Outage scheduled for 10/1)Aux Stm 50# header on ES 67.MSD system is shutdown.Tagging: Testing: Continue working the fire protection valve stroke Followup Items For scheduled maintenance dates on burdens, work arounds, CREOOS or OOS RE's see WSC Management or Ops Agenda at -S:\OWC\ops databases\Ops Agenda\agenda97.mdb INITIAL SUBMITTAL OF THE OUTLINE FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13,1999 4--,D`7 ArstEnpr Davis-Besse Nuclear Power Station F_ Oak Harbor Ohio 43449-9760 Guy G. Campbell 419-321-858 Vice President
-Nuclear Fax: 419-321-8337 Docket Number 50-346 License Number NPF-3 Serial Number 1-1186 June 24, 1999 Mr. H. Peterson Operator License Examiner -Region III United States Nuclear Regulatory Commission 801 Warrenville Road Lisle, IL 60532-4351
 
==Subject:==
Operator License Examination Materials
 
==
 
==Dear Mr. Peterson:==
==
Enclosed are operator license examination materials to support the operator license examinations being administered at the Davis-Besse Nuclear Power Station (DBNPS) during the week of September 13, 1999.The following confidential materials are submitted.
These materials shall be withheld from public disclosure until after the scheduled examinations are complete.* Outline for the September, 1999 operator license examination
* Copy of the audit examination administered to the operator license candidates
* Examination outlines from the 1997 and 1998 license examinations administered at the DBNPS.Reference materials to support your preparation for the exam are also included in this submittal.
A copy of the DBNPS Technical Specifications and the plant emergency procedure (DB-OP-02000) are enclosed.Mr. Scott Lindsay, Qualification Instructor, can respond to questions with regard to the submitted materials, at (419) 321-8176.JUH 2 9 1999 Docket Number 50-346 License number NPF-3 Serial Number 1-1186 Page 2 If you require additional information, please contact Mr. James L. Freels, Manager -Regulatory Affairs, at (419) 321-8466.Sincerely yours, DLM/dlc Enclosures cc: S. N. Bailey, DB-1 NRC/NRR Project Manager w/o K. S. Zellers, DB- 1 Senior Resident Inspector w/o USNRC Document Control Desk w/o Utility Radiological Safety Board w/o Docket Number 50-346 License Number NPF-3 Serial Number 1-1 186 Attachment Page 1 of 1 COMMITMENT LIST The following list identifies those actions committed to by the Davis-Besse Nuclear Power Station in this document.
Any other actions discussed in the submittal represent intended or planned actions by Davis-Besse.
They are described only as information and are not regulatory commitments.
Please notify the Manager -Regulatory Affairs (419-321-8466) at Davis-Besse of any questions regarding this document or associated regulatory commitments.
COMMITMENTS DUE DATE None N/A ES-201 Examination Outline Form ES-201-2 Quality Checklist Facility:
Davis-Besse Nuclear Power Station Date of Examination:
9/13/1999 Initials Item Task Description a b* c 1. a. Verify that the outline(s) fit(s) the appropriate model per ES-401. e M R b. Assess whether the outline was systematically prepared and whether all knowledge and ability (iS I categories are appropriately sampled. Ad T c. Assess whether the outline over-emphasizes any systems, evolutions, or generic topics.E N d. Assess whether the repetition from previous examination outlines is excessive.
: 2. a. Using Form ES-301-5, verify that the proposed scenario sets cover the required number of normal evolutions, instrument and component failures, and major transients.
S I b. Assess whether there are enough scenario sets (and spares) to test the projected number and M mix of applicants in accordance with the expected crew composition and rotation schedule without compromising exam integrity; ensure each applicant can be tested using at least one new or 0 4 significantly modified scenario, that no scenarios are duplicated from the applicants' audit test(s)*, and scenarios will not be repeated over successive days.c. To the extent possible, assess whether the outline(s) conform(s) with the qualitative and quantitative criteria specified on Form ES-301-4 and described in AppendixD.
D. ,__3. a. Verify that: (1) the outline(s) contain(s) the required number of control room and in-plant tasks, -W (2) no more than 30% of the test material is repeated from the last NRC examination,/ (3)* no tasks are duplicated from the applicants' audit test(s), and -T (4) no more than 80% of any operating test is taken directly from the licensee's exam banks.b. Verify that: (1) the tasks are distributed among the safety function groupings as specified in ES-301, (2) one task is conducted in a low-power or shutdown condition, -Ad (3) 40% of the tasks require the applicant to implement an alternate path procedure, (4) one in-plant task tests the applicant's response to an emergency or abnormal condition, and -(5) the in-plant walk-through requires the applicant to enter the RCA. -c. Verify that the required administrative topics are covered, with emphasis on performance-based
*'activities.
: d. Determine if there are enough different outlines to test the projected number and mix of applicants and ensure that no items are duplicated on successive days. _4. a. Assess whether plant-specific priorities (including PRA and IPE insights) are covered in the appropriate exam section.G E b. Assess whether the 10 CFR 55.41/43 and 55.45 sampling is appropriate.
N E c. Ensure that K/A importance ratings (except for plant-specific priorities) are at least 2.5.R A d. Check for duplication and overlap among exam sections.L e. Check the entire exam for balance of coverage.
_M f. Assess whether the exam fits the appropriate job level (RO or SRO). 4A4 P inied me / Signature Date a. Author b. Facility Reviewer(*)
C I C c. Chief Examiner "Of- -.i d. NRC Supervisor L vC&/Z (*) Not applicable for NRC-developed examinations.
/ -, tu,4- ' 3d, V ES-301 Administrative Topics Outline Form ES-301-1 Facility:
Davis Besse Nuclear Power Station Date of Examination:
9/13/1999 Examination Level (circle one): (&sect;/ SRO Operating Test Number: Administrative Describe method of evaluation:
Topic/Subject
: 1. ONE Administrative JPM, OR Description
: 2. TWO Administrative Questions A.1 Control of (1) Stroke timing of a Locked Valve.Locked Valves Surveillance (1) Perform compensatory calculations for inoperable computer Requirements alarms for axial imbalance and control rod insertion limits.A.2 Safety Tagging (1) Generate a safety tagout for a Stator Cooling Water Pump with the Nuclear Operations Management System (NOMS)unavailable.
A.3 Personal (1) Check out a radiation detector in the RRA Radiation Protection A.4 Emergency (1) Given dose assessment data, determine the appropriate Protective protective action recommendations.
Action Guidelines ES-301 Control Room Systems and Facility Walk-Through Test Outline Form ES-301-2 Facility:
Davis-Besse Nuclear Power Station Date of Examination:
9/13/1999 Exam Level (circle one): ( / SRO(I) / SRO(U) Operating Test No.: l B.1 Control Room Systems System / JPM Title Type Safety Code* Function a. ECCS / Return Decay Heat Train 1 to Low Pressure D,S,L 2 Injection Mode b. ECCS (LB LOCA) / Initiate Long Term Boron Dilution D,A,S 3 Flowpath c. RHR / Start High Pressure Injection Pump Upon Loss of a M,A,S,L 4p Decay Heat Pump d. CSS / Recover from Inadvertent Safeguards Actuation N,S 5 Levels 1-4 e. NNI / Restore ICS to Full Automatic Control N,S 7 f. IAS / Loss of Instrument Air Actions From the Control D,S 8 Room g. WGDS / Purge Containment in Mode 5 D,A,S,L 9 B.2 Facility Walk-Through
: a. SWS (loss of NSW) / Use Circulating Water to Supply D,L 4s Service Water Primary Loads b. AC Electrical
/ Local Transfer of 13.8 KV Bus A Source N,A,L 6 c. CRD (Dropped Control Rod) / Clear Asymmetric Fault D,R 1* Type Codes: (D)irect from bank, (M)odified from bank, (N)ew, (A)lternate path, (C)ontrol room, (S)imulator, (L)ow-Power, (R)CA ES-301 Simulator Scenario Quality Checklist Form ES-301-4 Facility:
Davis-Besse Nudear Power Station Date of Exam:9113/1999 Scenario Numbers: 3/4! Operating Test No.: QUALITATIVE ATTRIBUTES Initials a b c 1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of service, but it does not cue the operators into expected events. _ l 2. The scenarios consist mostly of related events. 4 3. Each event description consists of l* the point in the scenario when it is to be initiated l the malfunction(s) that are entered to initiate the event l* the symptoms/cues that will be visible to the crew l* the expected operator actions (by shift position)the event termination point (if applicable)
: 4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario without a credible preceding incident such as a seismic event. 'A" l 5. The events are valid with regard to physics and thermodynamics.
4 > -6. Sequencing and timing of events is reasonable, and allows the examination team to obtain complete evaluation results commensurate with the scenario objectives.
: 7. If time compression techniques are used, the scenario summary clearly so indicates.
Operators have sufficient time to carry out expected activities without undue time constraints.
Cues are _ 4 given.8. The simulator modeling is not altered. ___ __9. The scenarios have been validated.
Any open simulator performance deficiencies have been evaluated to ensure that functional fidelity is maintained while running the planned scenarios.
al10. Every operator will be evaluated using at least one new or significantly modified scenario.
All other scenarios have been altered in accordance with Section D.4 of ES-301. __ X____II. All individual operator competencies can be evaluated, as verified using Form ES-301-6 (submit the form along with the simulator scenarios).
: 12. Each applicant will be significantly involved in the minimum number of transients and events specified on Form ES-301-5 (submit the form with the simulator scenarios). ( _13. The level of difficulty is appropriate to support licensing decisions for each crew position.
4W L TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO; SEE SECTION D.4.D) Actual Attributes
_ --1. Total malfunctions (5-8) /_/_2. Malfunctions after EOP entry (1-2) 2 I ':zI -3. Abnormal events (2-4) Al/ A f iX 4. Major transients (1-2) /_/_5. EOPs entered/requiring substantive actions (1-2)6. EOP contingencies requiring substantive actions (0-2) l / ( / 4 -7. Critical tasks (2-3) I lfI4H F-c;7in1 Trsnncignnt nH FPtnnt (~hgnl-ict CF^rm C:Q_#21_r,._ WI .-C t 1 L t4* *. LvLI w I1/4:;-5rvflOL III Il co-vu I -Ij OPERATING TEST NO.: Aplicant Evfiu t ion ininur m Scenario Number Iype Iype ur mr 4M=T_ _ _ _3 4 Reactivity 1 3 2 Normal 1 1 1 RO Instrument 2 4, 6 3,5 Component 2 2, 5 4,6 Major 1 7 7 = =Reactivity 1 Normal 0 As RO Instrument 1 = = = =Component 1 Major 1 = = =SRO-1 Reactivity 0 = = = =Normal 1 As SRO Instrument 1 Component 1 = = ___ __ __ __ _ Major 1 = =__ ==__ __Reactivity 0 _Normal 1 l l SRO-U Instrument 1 = =_l_lComponent 1 l l Major 1 l l Instructions:
(1)(2)Enter the operating test number and Form ES-D-1 event numbers for each evolution type.Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.4.d) but must be significant per Section C. .a of Appendix D.A + "17 (-et at YOCFLXW Author: Chief Examiner:
ES-301 Competencies Checklist Form ES-301-6 Applicant
#1 Applicant
#2 RO/SRO-I/SRO-U RO/SRO-I/SRO-U Competencies SCENARIO _ SCENARIO 3 4 __ _ 3 4 _ _Understand and Interpret 3, 5, 6, 4, 5. 6, 2, 4, 7, 3, 6 Annunciators and Alarms 7, 8 10 9 Diagnose Events 3, 5, 6, 4, 5, 9, 2, 4, 7, 3, 6, 7 and Conditions 7, 8 10 9 Understand Plant 3, 5, 6 1, 2, 4, 1, 2, 3, 2, 3, 6, and System Response 5,'8, 4, 7, 9 7, 8,10 9,10 _ _ _Comply With and 3,5,7, 1,2,4, 1,2,3, 2,3,6, Use Procedures (1) 8 6, 8, 9, 4,7, 9 7, 8, 10 Operate Control 3, 5, 6, 1, 2, 4, 1, 2, 3, 2, 3, 6, Boards (2) 7,8 5, 8,9, 4,7,9 7,8,10 Communicate and 3, 5, 6, 1, 2, 4, 1, 2, 3, 2, 3, 6, Interact With the Crew 7, 8 5, 6, 8, 4, 7, 9 7, 8,10_______ _______ ______ ______ ______ 9, 10 _ _ _ __ _ _ _ _ _ _ _Demonstrate Supervisory Ability (3)Comply With and Use Tech. Specs. (3)Notes: (1) Includes Technical Specification compliance for an RO.(2) Optional for an SRO-U.(3) Only applicable to SROs.Instructions:
Circle the applicant's license type and enter one or more event numbers that will allow the examiners to evaluate every applicole competency for every applicant.
Author: /gr IA vt s O Y A Z Chief Examiner:
Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 3 Op-Test No.: 1 Examiners:
Operators:
Objectives:
The RO candidates are to (1) perform the Weekly T-G Overspeed Trip Mechanism test, (2)reduce Reactor power to <80% to recover a dropped control rod in Group 7, (3) manually control both Main Feedwater Pump Turbines due to FW Valve Delta-P instrument failing high, (4) start the standby TPCW pump, (5) start Makeup Pump 2 due to Makeup Pump 1 tripping, (6) minimize the iniection of BWST inventory due to Makeup tank level failing low, (7) recover an essential bus due to a loss of power and (8) actuate SFRCS at the component level.Turnover:
10 gpd tube leak on Steam Generator
: 2. Planned: Weekly T-G Overspeed Trip Mechanism test. Equipment Out of Service: EDG 1 to change out contaminated lube oil, SAC 1 for.PMs.Event l Malf. No. l Event l Event No. l Type* l Description 1 N(BOP) Perform Weekly T-G Overspeed Trip Mechanism test.2 IMF KDP213 C(BOP) Turbine Plant Cooling Water Pump 2 Trips.TRUE 3 IMF L1lOB R(RO) Drop a Control Rod in group 7 (rod 1).TRUE 4 IMF LlTSH I(BOP) Feedwater Valve Delta-P instrument, PDT SP5B1, fails Low 0.0 after Control Rod 7-1 has been recovered and ICS is full automatic.
5 IMF B2M11 C(RO) Trip Makeup pump 1.TRUE 6 IMF B2L1J I(RO) Both Makeup tank level indicators fail low after Pressurizer Level TRUE control and Seal Injection flow have been reestablished.
IMF B2L2J TRUE 7 IMF P1ZZ M(AII) After the power reduction has been started a Loss of Off-site TRUE Power occurs.8 IMF G528B C(RO) EDG 2 breaker trips on Generator Differential with a 30 second TRUE time delay.9 IMF F300 C(BOP) SFRCS fails to automatically or manually to actuate.TRUE* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 10f 9 Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 4 Op-Test No.: 1 Examiners:
Operators:
l Objectives:
The RO candidates are to (1) perform a transfer from four Circ. Water pumps operating to three Circ. Water pumps operating, (2) lift off of Low Level Limits, (3) place MU 32 into hand and transfer Pressurizer level to a good instrument, (4)start SAC 1 due to a failure to automatically start when needed, (5) isolate Letdown due to a Steam Generator Tube Leak and initiate a plant shutdown, (6) stop the Steam Generators from overfilling, (8) shutdown the plant using the SGTR EOP and trip the Reactor, (9) manually trip the Main Turbine, and initiate HPI/MU/PORV cooling due a steam leak in the good Steam Generator.
Turnover:
10 gpd Tube leak on Steam Generator
: 2. Planned: Switch from four Circ. Water pumps operating to three Circ. Water pumps operating for maintenance on Circ. Water pump 4 and continue plant startup.-
Lift off Low Level Limits. Completed:
maintenance on SAC 2 and returned to service, all testing of MDFP in the AFW Mode .Equipment out of Service: CCW pump 2 for PMs and EDG 2 to change out contaminated lube oil.Event Malf. No. Event Event No. Type* Description 1 N(BOP) Switch from four Circ. Water pumps operating to three Circ.Water pumps operating, shutdown Circ. Water pump 4.2 R(RO) Raise reactor power from 28% to 35% to lift of Low Level Limits.3 IMF H152C I(RO) Pressurizer Level, LT RC14-2, fails low.TRUE 4 IMF KFS1 G C(BOP) Trip Station Air Compressor 2 with a failure of Station Air TRUE Compressor 1 to automatically start after Pressurizer Level IMF KFS20 control has been reestablished.
TRUE l 5 IMF FATMD I(BOP) Deaerator Storage Tank 2 level, LT 420, control signal fails low.TRUE 6 IMF HH51 C(RO) Steam Generator 2 Tube leak of 75 gpm builds over 10 minutes 0.015 after Deaerator Level has been restored to normal.7 IMF HH51 0.09 M(AII) Steam Generator Tube Rupture of 450 gpm after a plant shutdown has been started.8 N(AII) Rapid shutdown to Low Level Limits.1of 12 Appendix D Scenario Outline Form ES-D-1 9 IMF L7 EHC C(BOP) Turbine fails to trip with SFRCS failing to automatically actuate.TRUE IOR Al11A1A19S1-1 OFF IMF FA300 TRUE 10 IMF SA05D 0.5 C(RO) Main Steam Safety Valve on Steam Generator 1 sticks 20%open when Reactor trips.* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2of 12 ES-301 Simulator Scenario Quality Checklist Form ES-301-4 Facility:
Davis-Besse Nuclear Power Station Date of Exam:9/13/1999 Scenario Numbers: 1 / 2 Operating Test No.: QUALITATIVE ATTRIBUTES Initials a b c 1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of , X service, but it does not cue the operators into expected events.2. The scenarios consist mostly of related events.3. Each event description consists of* the point in the scenario when it is to be initiated the malfunction(s) that are entered to initiate the event* the symptoms/cues that will be visible to the crew* the expected operator actions (by shift position)* the event termination point (if applicable)
: 4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario without a credible preceding incident such as a seismic event. A 7 5. The events are valid with regard to physics and thermodynamics.
If 6. Sequencing and timing of events is reasonable, and allows the examination team to obtain complete evaluation results commensurate with the scenario objectives.
: 7. If time compression techniques are used, the scenario summary clearly so indicates.
Operators have sufficient time to carry out expected activities without undue time constraints.
Cues are 6" given.8. The simulator modeling is not altered. it_ X 9. The scenarios have been validated.
Any open simulator performance deficiencies have been evaluated to ensure that functional fidelity is maintained while running the planned scenarios.
: 10. Every operator will be evaluated using at least one new or significantly modified scenario.
All id other scenarios have been altered in accordance with Section D.4 of ES-301. -0 ___11. All individual operator competencies can be evaluated, as verified using Form ES-301-6 (submit the form along with the simulator scenarios).
__ i,_12. Each applicant will be significantly involved in the minimum number of transients and events specified on Form ES-301-5 (submit the form with the simulator scenarios).
____13. The level of difficulty is appropriate to support licensing decisions for each crew position.TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO; SEE SECTION D.4.D) Actual Attributes
_ _ _1. Total malfunctions (5-8) g I __l___2. Malfunctions after EOP entry (1-2) _1/3. Abnormal events (2-4)4. Major transients (1-2) 2~5. EOPs entered/requiring substantive actions (1-2) / / I / -6. EOP contingencies requiring substantive actions (0-2) / /0 C / _7. Critical tasks (2-3) a /j l _ _
ES-301 Transient and Event Checklist Form ES-301-5 OPERATING TEST NO.: Ap-licant Evfution inimum Scenario Number Iype Iype u mber 12=1 2 _ __Reactivity 1 1 1 Normal 1 2 2 RO Instrument 2 4, 6 4, 6 Component 2 3, 5 3, 5 Major 1 7 8 Reactivity 1 Normal 0 As RO Instrument 1 _Component 1 Major 1 SRO-I Reactivity 0 = = = =Normal 1 As SRO Instrument 1 = = = =Component 1 Major 1 Reactivity 0 = = = =Normal I SRO-U Instrument 1 .Component 1 Major 1 Instructions:
Author: (1) Enter the operating test number and Form ES-D-1 event numbers for each evolution type.(2) Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.4.d) but must be significant per Section C.2.a of App dix D._ /2i; Xr Vo i- -- -- 7 Chief Examiner:
ES-301 Competencies Checklist Form ES-301-6 Applicant
#1 Applicant
#2 RO/SRO-I/SRO-U RO/SRO-I/SRO-U Competencies SCENARIO SCENARIO 1 2 1 2== _Understand and Interpret 4, 5, 2, 3, 4, 3, 6, 7 5, 6. 7, Annunciators and Alarms 5, 6, 7, 8, 9 Diagnose Events 4, 5 2, 3,4, 3, 6, 7 5, 6, 7, and Conditions 5, 6,7, 8, 9 Understand Plant 1,4,5, 1,2,3, 2,3,6, 1,5,6, and System Response 7 4, 6, 7, 7 7, 8, 9 Comply With and 1,4, 5, 1, 2, 3, 2, 6, 7 1, 5, 6, Use Procedures (1) 7 4, 6, 9 8,9 Operate Control 1,4 5, 1, 3,4, 2,3, 5, 1, 5, 6, Boards (2) 7 6, 9 6, 7 8, 9 Communicate and 1,4, 5, 1, 3, 4, 1, 2, 3, 1, 5, 6, Interact With the Crew 7 6, 7, 9 4, 6, 7 7, 8, 9 Demonstrate Supervisory Ability (3)Comply With and Use Tech. Specs. (3)Notes: (1) Includes Technical Specification compliance for an RO.(2) Optional for an SRO-U.(3) Only applicable to SROs.Instructions:
Circle the applicant's license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
Author: X 4e /r r LOf_Yk.1".- -I _X Chief Examiner:
Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: I Op-Test No.: 1 Examiners:
Operators:
lObjectives:
The RO candidates are to (1) perform the operator actions during a Plant startup beginning at 5% power and increase power to 10% or greater, (2) implement the actions for a power range NI failing high, (3) determine the need to trip the Main Turbine due to a Main Stop Valve failing open during Main Turbine Shell warming, (4) start Makeup Pump 2 due to a oil leak on Makeup Pump 1, (5) stop the Steam Generator 1 overfill due to Steam Generator 1 Startup Level instrument failing high, (6) trip the reactor due to a steam leak on AFPT 2, (7)establish MU/HPI cooling and (8) feed Steam Generator 2 with the Startup Feedwater Pump due to a loss of all feedwater.
Turnover:
Plant was shutdown for bushing replacement on the Main Transformer, Reactor startup is in progress and currently at -5%. Completed testing of both AFPTs for operability.
Planned: Continue Reactor startup and begin Main Turbine shell warming. In Progress:
Line-ups for placing MDFP in AFW mode, I&C changing RE600 & RE609 set point. Equipment OOS: Stator Coolant Pump B for motor replacement.
Event Malf. No. l Event Event No. j Type* Description 1 R(RO) Continue Reactor startup from about 5% to about 14%.2 N(BOP) Establish Main Turbine shell warming.3 IMF UV02C C(BOP) Fail open Main Turbine Stop valve 2 after Main Turbine shell TRUE warming has been started.4 IMF R3N5 100 I(RO) Fail Power Range Nuclear Instrument, NI-5, high.IMF R3N1 100 5 IMF BME5J C(RO) Oil leak on Makeup pump 1 after the Rod Control panel is placed 0.5 in automatic..
6 IMF L1TL28 I(BOP) Slow failure of Steam Generator 1 Startup level, LT SP9B4, to 0.0 zero.7 IMF FKPBC M(AII) After Steam Generator 1 level control has been established or TRUE C(AII) the Reactor trips a steam leak on AFPT 2 occurs with MS 1 07A IMF SFEG 1.0 failed open position.IMF SFECD Loss of All Feedwater due to steam leak on AFPT 2 and AFPT 1 1.0 Governor controlling at 500 rpm.500 Motor Drive Feed Pump's breaker will not close.* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 13 Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 2 Op-Test No.: 1 Examiners:
Operators:
Objectives:
The RO candidates are to (1) perform a power increase beginning at 40% power to -50% or areater. (2) startup MFPT 1. (3) identifv a sheared shaft on a Condensate PumD and start the standby Condensate Pump, (4) control the amount of steam being release through AVV 2 and TBV 2 due to the Steam Generator 2 Outlet pressure instrument failure. (5) determine that a Letdown Cooler is leakina and isolate it. (6) determine that the Reactor Demand and Feedwater Loop demands must be placed in manual due to the T-hot instrument failure and (7) trip all RCPs for the loss of SCM due to the Pressurizer Code Safety failing open.Turnover:
Plant is currently at -40%, plans are to continue raising power to 50% at 5 MWe/minute and startuD MFPT 1 .Eauioment OOS: MakeuD pump 1 for bearing replacement and TPCW DumD 1 for PMs.Event l Malf. No. l Event Event No. l Type* Description 1 R(RO) Raise power from 40% to 50%.2 N(BOP) Startup MFPT 1.3 IMF FAK40 C(BOP) Sheared shaft on Condensate Pump 1 after the startup of MFPT TRUE 1.4 IMF L1T334 I(BOP) Steam Generator 2 Outlet Pressure 'X' instrument, PT SP12A2, 1.0 failed high.5 IMF BME1B C(RO) Letdown Cooler 1 leaks into Component Cooling Water System 0.5 that develops over 5 minutes.6 IMF LIT6H 1.0 I(BOP) Slow mid-scale failure of RCS Loop 2 T-hot instrument, TT RC3A1 after Letdown has been restored.7 IMF FAAWB M(AII) After the plant has been stabilized with ICS station still in TRUE manual, Loop 1 and 2 Main Feedwater Block valves, FW779 and IMF FAB4B FW780, fail closed.TRUE 8 IMF HV40C M(AII) Pressurizer Code Safety fails open on a Reactor trip.TRUE 9 IMF FAAZC C(BOP) Main Feedwater Startup Control Valve, FW SP7A, fails open TRUE with SFRCS failing to automatically to actuate.IMF FA300 TRUE* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1of 11 ES-301 Simulator Scenario Quality Checklist Form ES-301-4l Facility:Davis-Besse Nuclear Power Station Date of Exam:9/13/1999 Scenario Numbers: 5/ / Operating Test No.: QUALITATIVE ATTRIBUTES Initials a b c 1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of 61'( t service, but it does not cue the operators into expected events. A L 2. The scenarios consist mostly of related events.3. Each event description consists of* the point in the scenario when it is to be initiated* the malfunction(s) that are entered to initiate the event I* the symptoms/cues that will be visible to the crew l* the expected operator actions (by shift position)* the event termination point (if applicable)
: 4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario 4Y without a credible preceding incident such as a seismic event.5. The events are valid with regard to physics and thermodynamics.
41 6. Sequencing and timing of events is reasonable, and allows the examination team to obtain complete evaluation results commensurate with the scenario objectives.
: 7. If time compression techniques are used, the scenario summary clearly so indicates.
Operators have sufficient time to carry out expected activities without undue time constraints.
Cues are 6 %*given.8. The simulator modeling is not altered. ___9. The scenarios have been validated.
Any open simulator performance deficiencies have been evaluated to ensure that functional fidelity is maintained while running the planned scenarios.
: 10. Every operator will be evaluated using at least one new or significantly modified scenario.
All t other scenarios have been altered in accordance with Section D.4 of ES-301. 2J 11. All individual operator competencies can be evaluated, as verified using Form ES-301-6 (submit the form along with the simulator scenarios).
: 12. Each applicant will be significantly involved in the minimum number of transients and events specified on Form ES-301-5 (submit the form with the simulator scenarios).
4*13. The level of difficulty is appropriate to support licensing decisions for each crew position.
_ -TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO; SEE SECTION DA) Actual Attributes l1. Total malfunctions (5-8) A 2. Malfunctions after EOP entry (1-2) Sal. I -3. Abnormal events (2-4) JJ I I -4. Major transients (1-2) L I___5. EOPs entered/requiring substantive actions (1-2) l I 6. EOP contingencies requiring substantive actions (0-2) I / / _____7. Critical tasks (2-3) __ -
ES-301 Transient and Event Checklist Form ES-301-5 OPERATING TEST NO.: Ap icant lution Minimum Scenario Number IIype umber 5 Reactivity 1 1 Normal 1 2 RO Instrument 2 5,6 _Component 2 3,4 Major 1 7 Reactivity 1 = =_=_Normal 0 As RO Instrument 1 = = = -Component 1 = =Major 1 SRO-l Reactivity 0 Normal 1 = lAs SRO Instrument 1 _Component 1_ _ _Major 1 _I_Reactivity 0 Normal 1 SRO-U Instrument I l _ll Component 1 l l l__ _ _ _ _ _M ajor 1 l l l Instructions:
Author: (1) Enter the operating test number and Form ES-D-1 event numbers for each evolution type.(2) Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.4.d) but must be significant per Section C.2.a jf Appendix D.i s_~ " -a X, i ----___ CT7 (7 Chief Examiner:
ES-301 Competencies Checklist Form ES-301-6 Applicant
#1 Applicant
#2 RO/SRO-I/SRO-U RO/SRO-I/SRO-U Competencies SCENARIO SCENARIO 5 = = =_= 5 =Understand and Interpret 3, 5, 7 4, 6, 7, Annunciators and Alarms Diagnose Events 3, 5, 7, 4, 6, 7, and Conditions 8 9 Understand Plant 1, 2,3, 1, 3,4, and System Response 5,7, 8 6, 7, 9 Comply With and 1, 2, 3, 3, 6, 7, Use Procedures (1) 4' 58 7', Operate Control 1, 2, 3, 3, 4, 6, Boards (2) 4, 5, 7, 7, 9 Communicate and 1,2, 3, 1, 3,4, Interact With the Crew 4' 58 7, 6, 7, 9 Demonstrate Supervisory Ability (3)Comply With and Use Tech. Specs. (3)Notes: (1) Includes Technical Specification compliance for an RO.(2) Optional for an SRO-U.(3) Only applicable to SROs.Instructions:
Circle the applicant's license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
Author: X _ z/rfen :Y&04 Chief Examiner:
Appendix D Scenario Outline Form ES-D-1 Facility:
Davis Besse NPS Scenario No.: 5 Op-Test No.:_ _Examiners:
Operators:
l Objectives:
The RO candidates are to (1) perform a power reduction from 100% to 93%for Control Rod testing. (2) reduce Reactor power to 72% and trip RCP 2-2 due to an oil leak, (3) control MFPT 1 manually on the MDT 20 due to the ICS demand failing to 100%, (4) control RCS pressure manually and transfer RCS pressure NNI input due to RCS pressure failing low, (5)transfer Steam Generator 2 Operate level from the 'X' instrument to the 'Y' instrument due to the temperature compensation failing low, (6) trip the Reactor due to a steam leak into Containment, (7) de-energize buses E2 and F2 due to an ATWS, and (8) start the Motor Driven Feed pump due to a loss of all AFW pumps.Turnover:
Planned: Lower power to 93% for Control Rod Exercising test and Main Turbine Control Valve testing. Equipment Out of Service: CCW pump 3 for PMs, AFW pump 2 for Outboard Pump bearing replacement.
Completed:
Maintenance and testing on CAC 2's breaker.Event Malf. No. Event Event No. Type* Description 1 R(RO-P) Reduce Reactor power from 100% to 93%.2 N(RO-P) Perform Control Rod Exercising test after power has been reduced to 93%.3 IMF L1 S3N 1.0 i(RO-S) Downcomer temperature on Steam Generator
: 1. TT SP8A1 fails high after RCS pressure control is returned to normal.4 IMF HU24 0.5 C(RO-P) Oil leak on RCP 2-2's upper reservoir after Control Rod group 1 has been exercised.
5 IMF SFR5A C(RO-S) ICS Demand to Main Feedwater Pump 1 fails to 100% after RCP 5300 2-2 has been tripped and the plant is stable.6 IMF L4P2D I(RO-P) RCS Loop 1 Pressure, PT RC2B2 fails low after manual control TRUE of MFP I has been established and the MFP flows are balanced.7 IMF SAM2 0.05 M(AII) A 5% Steam Leak on Steam Generator 2 into Containment develops after the Y Steam Generator 2 Operate Range has been selected.8 IMF L4 TRUE C(RO-P) An ATWS occurs that prevent CRD breakers from opening.9 IMF SFE8B C(RO-S) MS 106, Steam Generator 1 to AFPT 1, fails to open.TRUE* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor lof 12 ES-401 PWR RO Examination Out ilinia Fo~rm nt r-QAnd _' --40 -RO -m-i h_ I .I.. WIl Cl rJrI Facility:
Date of Exam: Exam Level: lK/A Category Points Tier Group Point K K K K K A A A A G Total l 2 3 4 5 6 1 2 3 4 *l 1. 1 3 2 3 3 3 2 16 Emergency
& 2 2 3 33 33 7 Abnormal Plant 2 2 3 3 3 3 3 17 Evolutions 3 1 0 1 0 3 Tier 6 5 6 7 7 5 36_______ ______ T otals _ _1 3 2 2 2 2 2 2 2 3 2 1 23 2. 2 2 2 3 2 0 1 2 2 2 2 2 20 Plant 2 2 2 1 2222 Systems 3 1 0 1 1 1 1 1 1 0 1 0 8 Tier 6 4 6 5 3 4 5 5 5 5 3 51 I! __________
_ I T otals ___3. Generic Knowledge and Abilities l Cat 1 Cat 2 Cat 3l Cat4 4 3 4 3 2 1 411 Note: 1. Ensure that at least two topics from every K/A category are sampled within each tier (i.e., the "Tier Totals" in each K/A category shall not be less than two).2. Actual point totals must match those specified in the table.3. Select topics from many systems; avoid selecting more than two or three K/A topics from a given system unless they relate to plant-specific priorities.
: 4. Systems/evolutions within each group are identified on the associated outline.5. The shaded areas are not applicable to the category/tier.
6.* The generic K/As in Tiers 1 and 2 shall be selected from Section 2 of the K/A Catalog, but the topics must be relevant to the applicable evolution or system.7. On the following pages, enter the K/A numbers, a brief description of each topic, the topics' importance ratings for the RO license level, and the point totals for each system and category.
K/As below 2.5 should be justified on the basis of plant-specific priorities.
Enter the tier totals for each category in the table above.33of 45 NUREG-1021, Revision 8 ES-401 PWR RO Examination Outline Form ES-401-4 Emergency and Abnormal Plant Evolutions
-Tier I/Group 1_ 1 E/APE # / Name / Safety Function Kl K2 K3 Al A2 G K/A Topic(s) Imp. Points 000005 Inoperable/Stuck Control Rod /1 1 AA1.01; CRDS 3.6 1 00001 5/17 RCP Malfunctions
/ 4 1 AK1.02; Consequences of an RCP seal failure 3.7 1 BW/E09; CE/A13; W/E09&E10 Natural Circ. / 4 1 EK3.2; Norm., abnorm. and emerg. op. proc. assoc. w/Natural Cir. C/D 3.0 1 000024 Emergency Boration / 1 1 AK1.01; Relationship between Boron Add'n and changes in Tave 3.4 1 000026 Loss of Component Cooling Water / 8 1 AA2.06; Time to component damage after loss of CCW 2.8 1 000027 Pressurizer Pressure Control System 1 AK3.03; Actions in EOP for PZR PCS Malfunction 3.7 1 Malfunction
/ 3 000040 (BW/E05, CE/E05, W/E12) Steam Line 1 EK2.1; Components and functions of control and safety systems 3.8 1 Rupture -Excessive Heat Transfer /4 CE/A1l; W/E08 RCS Overcooling
-PTS / 4 1 EA2.1; Facility cond. and selection of appropriate proc. during AB & EOP 3.4 1 000051 Loss of Condenser Vacuum / 4 1 AA2.02; Conditions requiring Rx and/or Turbine trip 3.9 1 000055 Station Blackout / 6 1 EA1.04; Reduction of loads on the battery 3.5 1 000057 Loss of Vital AC Elec. Inst. Bus / 6 1 1AA.06; Manual ctl of components for which auto control is lost 3.5 1 000062 Loss of Nuclear Service Water / 4 1 2.4.11; Knowledge of abnormal condition procedures 3.4 1 000067 Plant Fire On-site / 9 000068 (BW/A06) Control Room Evac. /8 000069 (W/E14) Loss of CTMT Integrity
/ 5 000074 (W/E06&E07)
Inad. Core Cooling / 4 _ 1 _ _ EK3.11; Guidance in EOP for ICC 4.0 1 BW/E03 Inadequate Subcooling Margin / 4 1 _ _ EK1.2; Norm, Abn, & Emerg. OPs assoc. w/ inadequate SCM 3.8 1 000076 High Reactor Coolant Activity / 9 1 2.3.10; Ability to perform proc. To reduce rad. levels & minimize exposure 2.9 1 BW/A02&A03 Loss of NNI-X/Y / 7 1 AK2.1; Components and functions of control and safety systems 3.8 1lK/A Category Totals: l3 l12 113 l3 13 12 [Group Point Total: [16 NUREG-1021, Revision 8 34 of 45 ES-401 PWR RO Examination Outline Form ES-401-4l Emergency and Abnormal Plant volutions
-Tier 1/Group 2 j E/APE # / Name / Safety Function Kl K2 K3 Al A2 G K/A Topic(s) Imp. Points 000001 Continuous Rod Withdrawal
/1 000003 Dropped Control Rod / 1 000007 (tBW/E02&E10; CE/E02) Reactor Trip -I EA1.1; Components and functions of control and safety systems 4.0 1 stabilization
-Recoveryf I _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _BW/ANI Plant Runback / 1 1 _ AK3.2; Norm., abnorm. and emerg. operating proc. assoc. with plant R/B 3.2 1 BW/A04 Turbine Trip / 4 1 AA2.1; Facility cond. and selection of appropriate proc. during AB & EOP 3.3 1 000008 Pressurizer Vapor Space Accident /3 3 l 000009 Small Break LOCA / 3 1 EA1.18; Balancing of HPI loop flows 3.4 1 000011 Large Break LOCA / 3 _ 1 EA2.01; Actions to be taken, based on RCS temp. & press. -Sat. & S/H 4.2 1 W/E04 LOCA Outside Containment
/ 3 _ lBW/E08; W/E03 LOCA Cooldown/Depress.
/4 1 _ EKI.2; Norm., abnorm. and emerg. operating proc. assoc. with LOCA C/D 3.5 1 W/El 1 Loss of Emergency Coolant Recirc. /4 4 _ _lW/EO1 & E02 Rediagnosis
& SI Termination
/ 3 _ 1 EK3.2; Norm., abnorm. and emerg. operating proc. assoc. with SI term. 3.3 1 000022 Loss of Reactor Coolant Makeup /2 000025 Loss of RHR System / 4 1 _ AK2.02; LPI or Decay Heat Removal/RHR pumps 3.2 1 000029 Anticipated Transient w/o Scram / 1 1 EK2.06; Breakers, relays, and disconnects 2.9 1 000032 Loss of Source Range NI / 7 1 _ AK3.01 ;Startup termination on source-range loss 3.2 1 000033 Loss of Intermediate Range NI / 7 1 _ AKI.01; Effects of voltage changes on performance 2.7 1 000037 Steam Generator Tube Leak / 3 1 2.4.4; Ability to recognize entry conditions for EOP and AOP 4.0 1 000038 Steam Generator Tube Rupture / 3 1 EAI.01; S/G levels, for abnorm. Increase in any S/G 4.5 1 000054 (CE/E06) Loss of Main Feedwater
/ 4 1 2.4.12;General operating crew responsibilities during emerg. ops 3.4 1 BW/Eo4; W/EO5 Inade uate Heat Transfer -Loss 1 EA2.1; Facility cond. and selection of appropriate proc. during AB & EOP 3.2 1 of Secondary HeatS 4 000058 Loss of DC Power / 6 _ _ 1 2.4.11; Knowledge of AOPs 3.4 1 000059 Accidental Liquid RadWaste Rel. / 9 _ 1 __ AK2.01; Radioactive-Liquid monitors 2.7 1 000060 Accidental Gaseous Radwaste Rel. /_9 000061 ARM System Alarms /7 W/E16 High Containment Radiation
/ 9 CE/E09 Functional Recovery K/A Category Point Totals: 2 3 3 l3 l3 3 Group Point Total: l 17 35 of 45 NUREG-1021, Revision 8 ES-401 PWR RO Examination Outline Form ES-401-4l Emergency and Abnormal Plant Evolutions
-Tier 1/Group 3 I E/APE # Name / Safety Function KI K2 K3 Al A2 G K/A Topic(s) Imp. Points 000028 Pressurizer Level Malfunction
/2 000036 (BW/A08) Fuel Handling Accident / 8 _A1 A1.3: Desired operating results during AB & EOP situations 3.7 1 000056 Loss of Off-site Power / 6 _ 1 AA2.37; EDG indications for volts, freg, load, load-status
& tie bkr status 3.7 1 000065 Loss of Instrument Air / 8 BW/E13&E14 EOP Rules and Enclosures BW/A05 Emergency Diesel Actuation
/6 1 AK1.3; Annunc. & Cond'ns indicating signals, & remedial actions 3.8 1 BW/A07 Flooding / 8 CE/Al 6 Excess RCS Leakage /2 _2_ _ _W/Ei3 Steam Generator Over-pressure
/ 4 I __W/E15 Containment Flooding /5 _i g pi I_ ______I i i i iI I _ _ _ _I_i i i_ _i i i_ _ I i I I K/A Category Point Totals: 1 1Group Point Total: 3 NUREG-1021, Revision 8 36 of 45 ES-401 PWR RO Examination Outline Form ES-401-4__ __Plan_ Plant Sys tems -Tier ./Group_ 1 __System # / Name K1 K2 K3 K4 K5 K6 Al A2 A3 A4 G K/A Topic(s) Imp. Points 001 Control Rod Drive I _ K5.09; Relationship between p [B] and p CR 3.5 1 001 Control Rod Drive -__1 K6.13; Location & operation of RPIS 3.6 1 003 Reactor Coolant Pump 1 _ _ K3.05; ICS 3.6 1 003 Reactor Coolant Pump -1 _ _ 1 A3.03; Seal D/P 3.2 1 004 Chemical and Volume Control 1 K1.15; ECCS 3.8 1 004 Chemical and Volume Control -1 _ A1.04; PZR pressure and level 3.9 1 013 Engineered Safety Features Actuation 1 K6.01; Sensors and detectors 2.7 1 013 Engineered Safety Features Actuation 1 A3.01; Input channels and logic 3.7 1 015 Nuclear Instrumentation 1 _ K2.01; NIS chnis., components, & interconn.
3.3 1 015 Nuclear Instrumentation
_ 1 _ A.03; trip bypasses 3.8 1 017 In-core Temperature Monitor _ 1 _ K4.01; Input to subcooling monitors 3.4 1 017 In-core Temperature Monitor -_ _ K5.02; Saturation and subcooling of water 3.7 1 022 Containment Cooling 1 _ _ K3.02; CTMT instr. Readings 3.0 1 022 Containment Cooling _I__ 1 _ A4.01; CCS fans 3.6 1 025 Ice Condenser 056 Condensate 1 _ ___ K1.03; MFW 2.6 1 056 Condensate
--1 2.1.28; Knowl. of purp. & func. of major sys. 3.2 1 059 Main Feedwater-
_ __ _ A1.03; Pwr Ivi restric. for ops of MFP & vIvs. 2.7 1 059 Main Feedwater
-1 A3.07; ICS 3.4 1 061 Auxiliary/Emergency Feedwater I ____ K2.01; AFW system MOVs 3.2 1 061 Auxiliary/Emergency Feedwater I A2.09; Total loss of FW TBD 1 068 Liquid Radwaste -1 A2.04; Failure of auto. isolation 3.3 1 071 Waste Gas Disposal _ 1 -_ K4.04; Isolation of WG release tanks 2.9 1 072 Area Radiation Monitoring 1 _ __ K1.01; Plant ventilation systems 3.1 1 K/A Category Point Totals: 3 2 2 2 2 2 2 2 3 2 1 Group Point Total: l 23 37of 45 NUREG-1021, Revision 8 ES-401 PWR RO Examination Outline Form ES-401-4 I --Plant S~ystems -Tier 2/Group 2 ---___-___System # Name KI K2 K3 K4 K5 K6 Al A2 A3 A4 G K/A Topic(s) Imp. Points 002 Reactor Coolant _ 1 --K4.10; Overpressure protection 4.2 1 006 Emergency Core Cooling -A2.12; Conditions req'ing ECCS actuation 4.5 1 010 Pressurizer Pressure Control -1 _ A1.01; PZR & RCS boron concentrations 2.8 1 011 Pressurizer Level Control _ 1 -K6.04; Ops of PZR level controllers 3.1 1 012 Reactor Protection
_ 1 _ A4.02; Components for ind. channels 3.3 1 014 Rod Position Indication
_ 1 _ A4.02; Control rod mode select switch 3.4 1 016 Non-nuclear Instrumentation
____ 1 _ A2.03; Interruption of xmitted signal 3.0 1 026 Containment Spray 1 _ K4.04; Red. of CTMT T & P post LOCA 3.7 1 029 Containment Purge 1 _ ___ K3.01; CTMT parameters 2.9 1 033 Spent Fuel Pool Cooling 1 2.1.32; Explain & apply all limits & precaut'ns 3.4 1 035 Steam Generator
-1 A3.01; S/G water level control 4.0 1 039 Main and Reheat Steam 1 A1.06; Main steam pressure 3.0 1 055 Condenser Air Removal 1 K3.01; Main condenser 2.5 1 062 AC Electrical Distribution 1 _ _ K1.04; Offsite power sources 3.7 1 063 DC Electrical Distribution 1 _ K2.01; Major DC loads 2.9 1 064 Emergency Diesel Generator 1 _ K3.02; ESFAS controlled or actuated systems 4.2 1 073 Process Radiation Monitoring 1 2.4.31; Knowledge of annun., alrms. & ind. 3.3 1 075 Circulating Water _ 1 -K2.03; Essen. SWS pumps 2.6 1 079 Station Air 1 _ K1.01; lAS 3.0 1 086 Fire Protection
-1 _ A3.02; Actuation of the FPS 2.9 1l K/A Category Point Totals: 1 2 12 3 [ 2 l 0 l 1 2 12 [2 l2 112 1 Group Point Total: l 20 NUREG-1021, Revision 8 38 of 45 ES-401 PWR RO Examination Outline Form ES-401-4__- Plant Systems Tier 2/Group 3 _System # Name K1 K2 K3 K4 K5 K6 Al A2 A3 A4 G K/A Topic(s) Imp. Points 005 Residual Heat Removal 1 _ _ K3.07; Refueling Ops 3.2 1 007 Pressurizer Relief/Quench Tank 1 A4.10; Recognition of leaking PORV/Code 3.6 1 008 Component Cooling Water -_ Al.01; CCW flow rate 2.8 1 l027 Containment Iodine Removal 028 Hydrogen Recombiner and Purge Control __ _ __l034 Fuel Handling Equipment
_ _ K6.02; Radiation monitoring systems 2.6 1 041 Steam Dump/Turbine Bypass Control -1 K5.07; Reactivity feedback effects 3.1 1 045 Main Turbine Generator 1 K4.11; T/G reactor trip 3.6 1 076 Service Water _ 1 _ _ A2.01; Loss of SWS 3.5 1 078 Instrument Air 1 _ K1.04; Cooling water to compressor 2.6 1 103 Containment K/A Category Point Totals: J 1 0 l I l I 1 0 l 0 Group Point Total: 8 Plant-Specific Priorities System / Topic Recommended Replacement for.. Reason PointslPlant-Specific Priority Total: (limit 10) l 39 of 45 NUREG-1021, Revision 8 ES-401 Generic Knowledge and Abilities Outline (Tier 3) Form ES-401-5 Facility:
Davis-Besse Date of Exam: 9/13/99 Exam Level: RO]Category K/A # Topic Imp. Points 2.1.7 Eval. Plant perf. & make oper. judgements 3.7 1 2.1.11 Knowledge of < 1 hr. Tech. Spec. Actions 3.0 1 Conduct of 2.1.23 Perf. systm & integr. pInt proc. during all modes 3.9 1 Operations 2.1.3 Recognize Tech. Spec. entry conditions 3.4 1 2.1. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _2.1. __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _Total 4 2.2.1 Perform pre-S/U proc. including p effects. 3.7 1 2.2.22 Knowedge of LCOs & safety limits 3.4 1 2.2.34 Knowledge of process for determining p effects 2.8 1 Equipment 2.2. _Control 2.2. l 2.2. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Total = 3 2.3.4 Knowledge of rad exposure & cont. limits 2.5 1 2.3.9 Knowl. of process for perfmce. of CTMT purge 2.5 1 2.3. l Radiation 2.3 l Control 2.3l 2.3. l 2.3. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Total = 2 2.4.1 Knowl. of EOP entry & Immed. Action 4.3 1 2.4.9 Low pwr/S/D implications for acc. mitigat. 3.3 1 Emergency 2.4.39 RO responsibilities.
in E-Plan implementation 3.3 1 Procedures/
2.4.45 Prioritize
& interpret alarms 3.3 1 Plan 2.4.2.4. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Total 4 Tier 3 Point Total (RO/SRO) 13/17 NUREG-1021, Revision 8 40 of 45 Frst ne Davis-Besse Nuclear Power Station gy 5501 North State Route 2 Oak Harbor, Ohio 43449-9760 Guy G. Campbell 419-321-858 Vce President
-Nuclear Fax. 419-321-837 Docket Number 50-346 License Number NPF-3 Serial Number 1-1190 July 26, 1999 Mr. H. Peterson Operator License Examiner -Region III United States Nuclear Regulatory Commission 801 Warrenville Road Lisle, IL 60532-4351
 
==Subject:==
Operator License Examination Submittal
 
==
 
==Dear Mr. Peterson:==
==
Enclosed are the written operator license examination and supporting materials, prepared by the staff of the Davis-Besse Nuclear Power Station (DBNPS) for the examination to be administered at the DBNPS during the week of September 13, 1999.The following items, which are considered confidential, are being submitted to the Nuclear Regulatory Commission for review and approval.
These materials shall be withheld from public disclosure until after the scheduled examination is complete.* A detailed listing of all materials submitted* Written operator license examination
* Five simulator examination scenarios* Ten walk-through examination job performance measures* Five administrative topics* Reference materials that support the examination materials listed above Mr. Scott Lindsay, Qualification Instructor, can respond to questions with regard to the submitted confidential materials at (419) 321-8176.
Docket Number 50-346 License number NPF-3 Serial Number 1-1 190 Page 2 If you require additional information, please contact Mr. James L. Freels, Manager -Regulatory Affairs, at (419) 321-8466.Sincerely yours, DLM/dlc Enclosures cc: S. N. Bailey, DB-1 NRC/NRR Project Manager w/o K. S. Zellers, DB-1 Senior Resident Inspector w/o USNRC Document Control Desk w/o Utility Radiological Safety Board w/o Docket Number 50-346 License Number NPF-3 Serial Number 1-1190 Attachment Page 1 of 1 COMMITMENT LIST The following list identifies those actions committed to by the Davis-Besse Nuclear Power Station in this document.
Any other actions discussed in the submittal represent intended or planned actions by Davis-Besse.
They are described only as information and are not regulatory commitments.
Please notify the Manager -Regulatory Affairs (419-321-8466) at Davis-Besse of any questions regarding this document or associated regulatory commitments.
COMMITMENTS DUE DATE None N/A INITIAL SUBMITTAL OF THE OPERATING TEST FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13, 1999 INITIAL SUBMITTAL OF THE ADMINISTRATIVE JPMS FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13,1999 DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: Al-I Rev. 00 Page 1 of 8 TASK NO.: 006-003-01-0403 TASK DESCRIPTION:
Perform Administrative Actions for Control of Locked Valves During Post Maintenance Valve Testing of HP 31 K/A
 
==REFERENCE:==
 
GEN 2.1.18 APPLICABLE METHOD OF TESTING: Actual Performance Simulator TIME FOR COMPLETION:
APPLICABILITY:
[XI RO 20 minutes[X] SRO TASK STANDARDS:
: 1. Documentation of HP 31 stroke test.2. Properly complete the Locked Valve Log 3. Notify the SS or Control Room SRO when Sheet.restoration is complete.REOUIRED MATERIALS:
DB-PF-03272, Post Maintenance Valve Test, Revision 1, Change 3, with the following entered:* Attachment 3 Parts I, II and III Block 1 with "HP31."* Attachment 3 Part I Block 8 with "NO" and an initial.Locked Valve Log Sheet with the following entered:* Valve/Component Number =HP31* Normal Position = OPEN* Reason for Change = DB-PF-03272
* Elec/Pneu
= checked* SS Permission
= initialed* Time & Date = current Copy of a M&TE data sheet for a VOTES test rig.GENERAL
 
==REFERENCES:==
 
DB-PF-03272.
Post Maintenance Valve Test, Revision 1, Change 3 DB-OP-00008, Operation and Control of Locked Valves, Revision 1, Change 3 JPM Al-1 Page 2 of 8 INITIAL CONDITIONS:
Maintenance has just completed packing adjustment on valve HP 31, HPI Pump 2 Recirc Stop Check Valve, to stop packing leakage per Work Order 99-003466-000. Electricians have installed VOTES testing equipment and are standing by with an equipment operator in the #1 ECCS Room. The Shift Supervisor has brought the Locked Valve Log to the Control Room.INITIATING CUES: The Shift Supervisor has given his permission to stroke HP 31, HPI Pump 2 Recirc Stop Check Valve, and directs you to perform post maintenance valve testing of HP 31 in accordance with DB-PF-03272, Post Maintenance Valve Test.(Hand a copy of DB-PF-03272, and Measure and Test Equipment Traveler to the examinee.)
JPM Al-i Page 3 of 8 INITIAL CONDITIONS:
Maintenance has just completed packing adjustment on valve HP 31, HPI Pump 2 Recirc Stop Check Valve, to stop packing leakage per Work Order 99-003466-000. Electricians have installed VOTES testing equipment and are standing by with an equipment operator in the #1 ECCS Room. The Shift Supervisor has brought the Locked Valve Log to the Control Room.INITIATING CUES: The Shift Supervisor has given his permission to stroke HP 31, HPI Pump 2 Recirc Stop Check Valve, and directs you to perform post maintenance valve testing of HP 31 in accordance with DB-PF-03272, Post Maintenance Valve Test.
JPM Al -I Page 4 of 8 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Perform administrative actions for control of locked valves during post maintenance valve testing of HP 31 INITIAL CONDITION:
Modes 1-3, any time in life.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
Ensure the Pump and Valve Basis Document and the Locked Valve Log are available.
MALFUNCTIONS/FAILURE TO INSERT: None.ACTION/CUES:
: 1. (Step 3) HP 31 is open.Electricians are ready for you to stroke HP 31.2. (Step 6) HP 31 is closed.3. (Step 8) Electricians are ready for you to stroke HP 31.
JPM Al- 1 Page 5 of 8 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C".standards for this item constitutes unless denoted in the "Comments".
Failure to meet any one of these failure. Sequence is assumed START TIME: 1. PERFORMANCE STEP: Review the procedure.
STANDARD:
Reviews the procedure.
CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Records known data on Attachment 3, Test Record, Parts I, and II.STANDARD: NOTE: Part I complete: MWO Number = 99-003466-000 OPERATOR = MOV CTMT ISO = NO MAXIMUM STROKE OPEN TIME = N/A MAXIMUM STROKE CLOSE TIME = 42.90 FAIL-SAFE POSITION = N/A Part II, columns 2-3 completed.
Stroke times will be obtained from the Pump & Valve Basis Document.COMMENT: Sign and date test data sheets for SRO concurrence (Part I, Column 10, Part II, Column 3).CUE: (If asked) The Shift Supervisor has reviewed the Test Requirements Sheet and no special requirements exist.SAT UNSAT 3. PERFORMANCE STEP: Verify HP 31 is open.STANDARD:
Observe Red light ON and Green light OFF. Communicate with the Equipment Operator to determine local valve position.CUE: None.SAT UNSAT JPM Al- 1 Page 6 of 8 4. PERFORMANCE STEP: Enter valve data on the Locked Valve Log Sheet and.C. obtain approval to position HP 31 from the Control Room SRO.STANDARD: Enter the following Change From Normal Position data on the Locked Valve Log Sheet and obtain approval to position HP 31 from the Control Room SRO:-Valve/Component Number =HP31-Normal Position = OPEN-Reason for Change = DB-PF-03272
-Elec/Pneu
= checked-SS Permission
= initialed-Time & Date = current COMMENT: This step may be performed any time prior to stroking HP 31.Initial in block labelled "SS Permission" and enter the time and date in the next block.CUE: None.SAT UNSAT 5. PERFORMANCE STEP: Stroke and time HP 31 closed..C.STANDARD: Press the close pushbutton and release.and Green light goes ON.Red light goes OFF COMMENT: VOTES equipment will determine the stroke time.CUE: (If asked) The electrician will provide the stroke time later when the work package is brought to the Control Room.SAT UNSAT 6. PERFORMANCE STEP: Verify HP 31 is closed.STANDARD:
Observe Control Room indications of valve position.Communicate with the Equipment Operator to determine local valve position.CUE: None.SAT UNSAT JPM Al- 1 Page 7 of 8 7. PERFORMANCE STEP:.C.Enter the valve position in the "Position To" block of the Locked Valve Log and initial in the "Positioned By" block.STANDARD:
Enter the valve position and initial.COMMENT: It is acceptable to complete the log entry after stroking the valve in both directions.
CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Stroke and time the valve open..C.STANDARD:
Press the open pushbutton and release. Green light goes OFF and Red light goes ON.CUE: None.SAT UNSAT 9. PERFORMANCE STEP:.C.Initial the "Restored By" block under "Restoration To Normal Position" in the Locked Valve Log.STANDARD:
Initial in the appropriate block.COMMENT: It is acceptable to complete both Locked Valve Log entries after stroking the valve in both directions.
CUE: None.SAT UNSAT 10. PERFORMANCE STEP: Complete the "Valve Position Indicator Lights Verified" blocks and record the as-left position in the Valve Restoration Position of the Test Record Part II data sheet.STANDARD:
Complete the specified blocks of the Test Record.CUE: (If asked) The Shift Supervisor wants HP31 to remain OPEN.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM Al- 1 Page 8 of 8 VERIFICATION OF COMPLETION Operator SSN License: Evalu Date[ I RO [ ] SRO [ I ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ I SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
D/Date Evaluator's Signature MEASURING AND TEST EQUIPMENT TRAVELER METS ACTIVITY NUMBER: Page: 1 of 1 DESCRIPTION OF M&TE M&TE MPL NO. LAST-CAL-DAT CAL-DUE-DATE VOTES EE0001.1 12/2/98 12/1/99 RECEIVED BY SSN DEPT SECT RELEASE BY HP TECH HP TECH SSN John Electro 000-00-0000 OPS E&C Joseph Doorman 111-11-1111 ISSUED BY SSN DEPT SECT ISSUE-DATE RETURN-BY ISSUED-FROM James Black 222-22-2222 OPS E&C 9/13/99 REMARKS: List every calibration and/or test this M&TE was used on. If M&TE was used for GO/NP GO Testing, Troubleshooting, or Functional Checks; identify in comment section. If No Recordable data is taken write ;NRDT;, if M&TE was Not Used, write 'NOT USED'DATE SR/SO/RT/SVI#/ETC.
EQUIPMENT-ID SYSTEM QA RANGE/FUNC USED ON M&TE USES PT COMMENTS The signature below is verification that all uses for the above M&TE have been documented on this traveler SSN#RETURNED BY: DATE: PLEASE DO NOT WRITE ON THE REVERSE SIDE OF THIS FORM DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: A1-2 Rev. 00 Page 1 of 8 TASK NO.: 015-005-02-0100 TASK DESCRIPTION:
Perform compensatory calculations for inoperable alarms for Axial Power Imbalance and Control Rod Limits.computer Insertion K/A
 
==REFERENCE:==
 
GEN-2.1.19 APPLICABLE METHOD OF TESTING: Actual Performance Simulator or Control Room TIME FOR COMPLETION:
APPLICABILITY:
[XI RO 10 minutes[X] SRO TASK STANDARDS:
: 1. Enter correct data on Attachments 1 and 4.2. Determine the correct operating limits for Attachments 1 and 4.REQUIRED MATERIALS:
DB-NE-03220, Imbalance, Tilt & Rod Index Revision 02 Technical Specifications Calcs -Group 38 Alarms Inoperable, GENERAL
 
==REFERENCES:==
 
DB-NE-03220, Imbalance, Tilt & Rod Index Calcs -Group 38 Alarms Inoperable, Revision 02 Technical Specifications INITIAL CONDITIONS:
Plant is operating at 100% power.EFPD is 350.0 EFPD.Full Incores are operable.INITIATING CUES: Reactor Engineering has informed the Shift Supervisor that the wrong limits were entered in Group 38 for axial power imbalance and control rod insertion making them inoperable.
The Shift Supervisor has directed you to perform DB-NE-03220, Imbalance, Tilt& Rod Index Calcs -Group 38 Alarms Inoperable accordingly.(Hand trainee a copy of DB-NE-03220)
JPM A1-2 Page 2 of 8 INITIAL CONDITIONS:
Plant is operating at 100% power.EFPD is 350.0 EFPD.Full Incores are operable.INITIATING CUES: Reactor Engineering has informed the Shift Supervisor that the wrong limits were entered in Group 38 for axial power imbalance and control rod insertion making them inoperable.
The Shift Supervisor has directed you to perform DB-NE-03220, Imbalance, Tilt& Rod Index Calcs -Group 38 Alarms Inoperable accordingly.
JPM Al- 2 Page 3 of 8 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Perform compensatory calculations for inoperable computer alarms for axial power imbalance and control rod insertion limits.INITIAL CONDITION:
100 % power MOL.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
None.MALFUNCTIONS/FAILURE TO INSERT: None.ACTION/CUES:
None.
JPM A1-2 Page 4 of 8 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C".standards for this item constitutes unless denoted in the "Comments".
Failure to meet any one of these failure. Sequence is assumed START TIME: l 1. PERFORMANCE STEP: Identify Attachment 1, Axial Power Imbalance Alarm Inoperable, requiring completion.
STANDARD:
Locate Attachment 1 of DB-NE-03220.
COMMENT: Prerequisites can be completed using initial cue data.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Enter the time.STANDARD:
Correct time entered.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Determine the percent full power source.STANDARD: Determine the source of the percent full power and enter the number 1 through 4 for the corresponding source.COMMENT: Highest NI -Group 38 should be selected four of the six choices is acceptable.
but any of the first CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Enter the percent full power..C.STANDARD: Enter the correct percent full power from the source selected in the previous step.CUE: None.SAT UNSAT JPM A1-2 Page 5 of 8 5. PERFORMANCE STEP: Determine the axial power imbalance source.STANDARD: Determine the source of the axial power imbalance and enter the number 1 through 4 for the corresponding source.COMMENT: NI Imbalance
-Group 38 should be selected but any of the first four of the five choices is acceptable.
CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Enter the values for the axial power imbalance..C.STANDARD:
Enter the correct values for the axial power imbalance from the source selected in the previous step.CUE: None.SAT UNSAT 7. PERFORMANCE STEP:.C.Determine the axial power imbalance limits based on the Core Operating Limits Report and enter them on Attachment 1.STANDARD: Locate figure 4b in the Core Operating Limits Report and enter values of _ and for the percent full power of _COMMENT: Trainee may use excore limits which are more conservative then incore limits.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Identify Attachment 4, Control Rod/APSR Insertion Alarm Inoperable, requiring completion.
STANDARD:
Locate Attachment 4 of DB-NE-03220.
COMMENT: Prerequisites can be completed using initial cue data.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Enter the time.STANDARD:
Correct time entered.CUE: None.SAT UNSAT JPM AI-2 Page 6 of 8 10. PERFORMANCE STEP: Determine the NI percent full power source.STANDARD: Determine the source of the NI percent full power and enter the number 1 through 4 for the corresponding source.COMMENT: Highest NI -Group 38 should be selected but any four of the five choices is acceptable.
of the first CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Enter the NI percent full power..C.STANDARD:
Enter the correct NI percent full power from the source selected in the previous step.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Determine the rod position source.STANDARD: Determine the source of the rod position and 1 through 4 for the corresponding source.enter the number COMMENT: Rod Position -Group 38 should be selected but any of the three choices is acceptable.
CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Enter the values for the rod index..C.STANDARD: Enter the correct values for the rod index from the selected source.CUE: None.SAT UNSAT JPM Al-2 Page 7 of 8 14. PERFORMANCE STEP: Determine the rod index limit based on the Core.C.........
Operating Limits Report and enter them on Attachment 1.STANDARD: Locate figure lb in the Core Operating Limits Report and enter value of for the NI percent Full Power of CUE: None.SAT UNSAT 15. PERFORMANCE STEP: Enter the values for the the APSR's Position..C.STANDARD:
Enter the correct values for the APSR's Position from the selected source.CUE: None. c SAT UNSAT 16. PERFORMANCE STEP: Determine the APSRs Position limit based on the Core Operating Limits Report and enter them on Attachment 1.STANDARD: Locate figure 3 in the Core Operating Limits Report and enter value of 0%.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM Al- 2 Page 8 of 8 Operator SSN License: VERIFICATION OF COMPLETION Evaluator_ Date[ ] RO W I SRO [ ] ONL Validated C Actual Comr Acceptable Result: Completion Time: iletion Time: minutes minutes Progress Maintained:
Yes No N/A[ I SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: A2 Rev. 00 Page 1 of 6 TASK NO.: 119-023-03-0100 TASK DESCRIPTION:
Generate a safety tagout for a Stator Cooling Water Pump with the Nuclear Operations Management System (NOMS)unavailable.
K/A
 
==REFERENCE:==
 
GEN-2.2.13 APPLICABLE METHOD OF TESTING: Actual performance Classroom or simulator TIME FOR COMPLETION:
33 minutes APPLICABILITY:
EX] RO [X] SRO TASK STANDARDS:
: 1. Identify that Attachment 2 has incorrect isolation boundaries.
: 2. Identify the correct procedure for isolation of the Stator Cooling Water Pump 1 on Attachment 4.3. Enter the correct isolation boundaries on Attachment 7 (see attached).
REOUIRED MATERIALS:
NG-DB-00250, Safety Tagging, Revision 00 and Prepare an Attachment 2 with the following information:
* Equipment Name: Stator Cooling Water Pump 1* Job No.: 99-003299-000
* Work Group: Mechanical Maintenance
* Description of Work: Replace the mechanical seal on Stator Cooling Water Pump 1* Requirements:
Check "Isolate Electrically," "Isolate Mechanically,""Vented," "Drained" and "Other." In the space under "other" enter: Y 01 -closed, Y 02 -closed and BF3124 (F31A) -open* Fill in a Requester, date, extension and work group Prepare an Attachment 3 with the following information:
* Date Placed: Current date* Clearance Number: 99-1240* SUS Number: 024-03* System/Component:
SBODG Air Compressor 1 (C340A)Have copies of Attachments 4, 5 and 7 Drawing OS-26, Revision 19 Davis-Besse Operations Valve Book Work Order Cover Sheet E-1040A, Electrical Distribution Book, Revision 255 DB-OP-06209, Stator Cooling Water System Operating Procedure, Revision 2, Change 1 JPM A2 Page 2 of 6 GENERAL
 
==REFERENCES:==
 
NG-DB-00250, Safety Tagging, Revision 00 Drawing OS-26, Revision 19 Davis-Besse Operations Valve Book E-1040A, Electrical Distribution Book, Revision 255 DB-OP-06209, Stator Cooling Water System Operating Procedure, Revision 2, Change 1 INITIAL CONDITIONS:
The plant is currently operating at 100%.Stator Cooling Water Pump 2 is in operation.
NOMS is currently out of service and will not be restored for another four hours.Thermography has found a hot spot on the lugs of the motor for Stator Cooling Water Pump 2.The Shift Supervisor has determined that Stator Cooling Water Pump 1 needs to be placed in service to replace Stator Cooling Water Pump 2 as soon as possible.
Stator Cooling Water Pump 1 has a leak on the pump's mechanical seal that must be replaced prior to placing it in service.INITIATING CUES: The Shift Supervisor has directed you to prepare a safety tagout for Stator Cooling Water Pump 1 for replacement of the mechanical seal.(Hand the trainee a prepared copy of Attachment 2 of NG-DB-00250 and Work Order Cover sheet.)
JPM A2 Page 3 of 6 INITIAL CONDITIONS:
The plant is currently operating at 100%.Stator Cooling Water Pump 2 is in operation.
NOMS is currently out of service and will not be restored for another four hours.Thermography has found a hot spot on the lugs of the motor for Stator Cooling Water Pump 2.The Shift be placed possible.seal that Supervisor has determined that Stator Cooling Water Pump 1 needs to in service to replace Stator Cooling Water Pump 2 as soon as Stator Cooling Water Pump 1 has a leak on the pump's mechanical must be replaced prior to placing it in service.INITIATING CUES: The Shift Supervisor has directed you to prepare a safety tagout for Stator Cooling Water Pump 1 for replacement of the mechanical seal.
JPM A2 Page 4 of 6 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate copy of NG-DB-00250, Safety Tagging.STANDARD:
Locate copy of NG-DB-00250, Safety Tagging.COMMENT: Sequence is not required for this JPM.Hand trainee a copy of NG-DB-00250.
CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Review the Clearance Request, Attachment 2.C..STANDARD:
Identify that Y 2 should be Y 3 and BF3124(F31A) should be BE3124 (E31A).COMMENT: The trainee should contact the requester about the errors.CUE: The requester agrees with your changes and asks you to change Clearance Request accordingly.
SAT UNSAT 3. PERFORMANCE STEP: Verify that no active clearance satisfies the boundaries of the Clearance Request.STANDARD:
Check with Shift Supervisor about the active clearance books.COMMENT: Provide cue only if trainee asks about existing active clearances.
CUE: There are no active clearances that support the boundaries of the Clearance Request.SAT UNSAT 4. PERFORMANCE STEP: Verify that no unsigned clearance satisfies the boundaries of the Clearance Request.STANDARD:
Check with Shift Supervisor about clearances that are not signed by the Clearance Authority.
COMMENT: Provide cue only if trainee asks about clearances with no Clearance Authority signature.
CUE: There are no unsigned clearances that support the boundaries of the Clearance Request.SAT UNSAT JPM A2 Page 5 of 6 5. PERFORMANCE STEP: Complete Clearance Cover Sheet, Attachment 4..C.STANDARD: Write in the "Remarks and Instructions' to remove Stator Cooling Water Pump 1 from service using DB-OP-06209, Stator Cooling Water System, Section 4.5 COMMENT: Provide trainee a copy of Attachment
: 4. Provide a copy of the SUS System list and Attachment 3, if requested.
NOTE: This step is NOT critical if vent and drain plug removal is identified on Attachment 7.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Complete Tag Assignment Sheet, Attachment 7..C.STANDARD: Enter the following components and positions:
Y 01, No. 1 SCW Pump Suction Vlv, -Closed.Y 03, No. 1 SCW Pump Discharge Vlv -Closed.BE3124(E31A), Gen Stator Clng Wtr Pmp 1 -Open.Stator Cooling Water Pump 1 -drain plug -removed (tagged or untagged).
Vent plug between SCW Pump 1 and Y 03 -removed (tagged or untagged).
COMMENT: Provide trainee a copy of Attachment 7.NOTE: Critical to identify removal of is not listed on Attachment 4.items is not critical; however, critical.vent and drain plugs if procedure The order of entry of the above proper sequencing of the tags is CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Complete Clearance Holder Sheet, Attachment 5.STANDARD:
Enter the appropriate data.COMMENT: Provide trainee a copy of Attachment 5.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM A2 Page 6 of 6 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ RO [ SRO [] ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date FEARMS DAVIS-BESSE PLANT SUB097-01 Work Order.9.9-003299-000 S Subsystem:
SUB097-01 Asset: SUB097-01 STATOR COOLING SYSTEM Problem Locn: *****_****_***
File no: 4503 Route: 00000 WO Type: Repetitive Action: CORRECTIVE MAINTENANCE Work Class: Shutdown:
N Mat.Acct:
4531.4531.IS.NP13B.DBRX.00000.00 Clearance:
Y Printed: 13-SEP-99 Clearance number: Quality Class: S Tech Spec: N Environmental Qualification:
N Test Requirements:
Y ASME Component:
Lead Craft: INST & TEST Repair Tag number: Train: Permission to Commence Work SS/SM Authorization:
DATE SUPERVISOR DATE Requested by: MECH PLANNER, Phone: 7237 Planner: DAVID TOWNER Phone: 7237 Work
 
== Description:==
 
Replace the mechanical seal on Stator Cooling Water pump 1.Work Order Review Lead Shop Review DATE Special Instructions:
Test Requirements:
Test Test Test Type Function Procedure Craft Signature Date 2 TSC SEE NOTE 1 BELOW OPS Test Requirements Comments: NOTE 1: VERIFY MECHANICAL SEAL DOES NOT LEAK AFTER THE PUMP IS RETURNED TO SERVICE.Page 1 of 5 FEARMS DAVIS-BESSE PLANT SUB097-01 Work Order 99-003299-000 S Subsystem:
SUB097-01 Technical Specifications None.Related Documents Foreign Material Exclusion Cleanliness Inspect Required N System Classification CLASS B Exclusion Zone Requirements ZONE 4 Accountability Checks Required N Control Access to Work Site N Install Clean Plugs/Covers N Special Work Practices N Secure Equipment N Foreign Items not Allowed Additional instructions Inspected By Signature Date Qualified Inspector Signature Date Permits RWP Page 2 of 5 A1TACHMFNT 2: CLEARA F CRREQUEST Requirements (Include recommended components to be taqced and their position)bSolated Electrically Isolated Mechanically 0 Grounded (Z-Vented Is-Drained 0 Brkr Removed fl System Breach 0 Other OPERATION'S REVIEW Page I of I ED 75A DAVIS-BESSE ADMINISTRATIVE PROCEDURE Safety Taggingy ATTACHMENT 3: CLEARANCE INDEX NG-DB-00250 Date Clearance SUS SYSTEM/COMPONENT Date Placed Number Number Noun Name, Equipment ID Number Removed Jjt_9jQ L'.2/4.O3 60'C'6 ,rt (/,n4 fc.s,AyrSo
/ (C-300c'.-)
Attachment 3 Page 1 of 1 ATTACHMFN 4: CLEANCE COVER SHET CLEARANCE COVER SHEET SUS NO. I CLEARANCE NO. REV. NO.l_ 7 0/1 ? F- /. /l I PAGE I OF, 2 NG-DB-00250 EQUIPMENT:
c CcihAfc-)cF-Av*itto /REQUESTED BY: SECTION: /c4e , PHONE/PAGER:
REQUEST FOR: DATE: / / SHIFT (M,D,E): DOES THIS CLEARANCE BREACH A CONTAINMENT PENETRATION? ( ] YES > NO OUTAGE CLEARANCE?
[ ] YES WORK TO BE DONE REMARKS AND INSTRUCTIONS CA~cj,,qto s-.^it bus sere e 4 t~/&deg;&deg;PREPARED BY: DATE: / / TIME: PLACEMENT REVIEW BY: DATE: / / TIME: SECTION CLEARANCE APPROVED:
DATE: / / TIME: CLEARANCE ISSUED: DATE: / / TIME: PREPARED BY: DATE: / I TIME: RESTORATION REVIEW & APPROVAL BY: DATE: / / TIME: SECTION CLEARANCE RELEASED BY: DATE: / / TIME: Attachment 4 Page I of I ATTACHMENT 5: CLEARANCE HOLDER SHEET CLEARANCE HT(OT.DER SHEET SUS NO. CLEARANCE NO. REV. NO._J5jj-c I 5 -/9? t/ 0 1 PAGER 0F9 NG-DB-00250
_ ._T7 AT -T IDTT VVLu I MIl.' I : WORK DOCUMEN WORK DESCRIPTION ACCEPTED BY PHONE/PAGE ACCEPT RELEASED (PRINT) NO. DATE/TIME/SI GDATE/TIME/SI A ~ e c ._ _ _ _ _ _N_I _ I _ I IJ I I Attachment 5 Page I of I ED 7575A DAVIS-BESSE ADMINISTRATIVE PRC Safety Tagging)CEDURE PAGE _ ---RfVL9N lPROCEDURE NUMBER PAG752 lA 00 l NG-DB-00250 ATTACHMENT 7: TAG ASSIGNMENT SHEET TAG ASSTGNMENT SHRET Attachment 7 Page I of I DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: A3 Rev. 00 Page 1 of 6 TASK NO.: 000-058-05-0100 TASK DESCRIPTION:
Check Out a Radiation Detector in the RRA K/A
 
==REFERENCE:==
 
GEN-2.3.5 APPLICABLE METHOD OF TESTING: Actual performance In-plant TIME FOR COMPLETION:
APPLICABILITY:
[X] RO[XJ SRO TASK STANDARDS:
: 1. Ensure the portable 2. Verify the portable 3. Ensure the portable a source check.radiation detector is within the Calibration due date.radiation detector is functional.
radiation detector has been source checked or perform REOUIRED MATERIALS:
Radiation Detector Check Source GENERAL
 
==REFERENCES:==
 
DB-HP-01103, Use of Portable Radiation, Contamination and Airborne Survey Equipment, Revision 01, Change 2 DB-HP-00010, Radiation Measuring and Test Equipment Calibration and Control Program, Revision 03, Change 4 INITIAL CONDITIONS:
A large break LOCA has occurred.LPI Pump 2 failed to start.The motor outboard bearing temperature on LPI pump 1 is slowly increasing.
INITIATING CUES: The Shift Supervisor has directed you to inspect the motor on LPI Pump 1 for a potential cause.RP coverage is not available and you are required to obtain a portable radiation detector prior to entering RRA.
JPM A3 Page 2 of 6 INITIAL CONDITIONS:
A large break LOCA has occurred.LPI Pump 2 failed to start.The motor outboard bearing temperature on LPI Pump 1 is slowly increasing.
INITIATING CUES: The Shift Supervisor has directed you to inspect the motor on LPI Pump 1 for a potential cause.RP coverage is not available and you are required to obtain a portable radiation detector prior to entering RRA.
JPM A3 Page 3 of 6 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C".standards for this item constitutes unless denoted in the "Comments".
Failure to meet any one of these failure. Sequence is assumed START TIME: 1. PERFORMANCE STEP: Locate a copy of DB-HP-01103, Use of Portable Radiation, Contamination and Airborne Survey Equipment.
STANDARD:
Obtain a copy of DB-HP-01103.
COMMENT: Trainee may elect to use his memory to perform this task.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Obtain a Portable Radiation Detector..C.STANDARD:
Obtain a Bicron RSO-5 or an Eberline R02 at the enterance to the RRA.CUE: None.SAT UNSAT 3. PERFORMANCE STEP:.C.Ensure instrument is not past its calibration due date.STANDARD:
Verify the date on the "Calibration" sticker has not been exceeded.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Inspect for physical damage..C.STANDARD:
Physically inspect the instrument for any damage.CUE: None.SAT UNSAT JPM A3 Page 4 of 6 5. PERFORMANCE STEP: Ensure the mechanical zero is correct.STANDARD:
Verify that the instrument's output meter reads zero with the.instrument off.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Turn on the instrument and verify the electronic zero is correct.STANDARD:
Turn on the instrument and verify that it is electronically zeroed.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Perform a battery check..C.STANDARD:
Ensure the instrument indicates the battery is good.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Ensure the completion of, or perform a source check.C ........ on the instrument.
STANDARD:
Verify the "Daily Source Check" sticker is initialled or verify the instrument's response is within + 20% of source's value.COMMENT: Critical if the "Daily Source Check" sticker has not been initialed for present date.CUE: None.SAT UNSAT JPM A3 Page 5 of 6 9. PERFORMANCE STEP: Perform a response check on the instrument.
STANDARD:
Verify up scale response of the instrument when placed near the check source.COMMENT: Critical if the trainee did not perform the actual daily source check.CUE: None.SAT UNSAT 10. PERFORMANCE STEP: Sign out the instrument.
STANDARD:
Fill out the Instrument Use/Response Log, Attachment 7 of DB-HP-00010, Radiation Measuring and Test Equipment Calibration and Control Program.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM A3 Page 6 of 6 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [] RO [] SRO [ ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ J UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: A4 Rev. 00 Page 1 of 5 TASK NO.: 000-080-05-0100 TASK DESCRIPTION:
Given Dose Assessment Data, Determine the Appropriate Protective Action Recommendations K/A
 
==REFERENCE:==
 
GEN-2.4.44 APPLICABLE METHOD OF TESTING: Actual performance Classroom or simulator TIME FOR COMPLETION:
APPLICABILITY:
[X] RO 10 minutes[XI SRO TASK STANDARDS:
Determine protective action recommendations based on given dose calculations.
REQUIRED MATERIALS:
RA-EP-02245, Protective Action Guidelines, Revision 0, Change 1.Fill out an Off-site Dose Assessment Nomogram with following information:
* Stability Class = E* Wind Speed = 1 mph* Flow Rate = 146 KCFM* Radiation Monitor Reading = 0.1 pCi/cc* 0.75 mile = 5.5 rem/hr.* 2 miles = 1.1 rem/hr.* 5 miles = 0.37 rem/hr.* 10 miles = 0.14 rem/hr.GENERAL
 
==REFERENCES:==
 
PA-EP-02245, Protective Action Guidelines, Revision 00, Change 1.INITIAL CONDITIONS:
A large break LOCA is in progress with no indications of core melt.Containment has been breached and a release from the station vent is in progress.DADS is out of service.The current wind direction is 300&deg;.INITIATING CUES: The Shift Supervisor has determined the off-site dose rate using a nomogram.The Shift Supervisor directs you to determine the off-site protective action recommendations using the TEDE values only.(Hand the examinee the nomogram.)
JPM A4 Page 2 of 5 INITIAL CONDITIONS:
A large break LOCA is in progress with no indications of core melt.Containment has been breached and a release from the station vent is in progress.DADS is out of service.The current wind direction is 3000.INITIATING CUES: The Shift Supervisor has determined the off-site dose rate using a nomogram.The Shift Supervisor directs you to determine the off-site protective action recommendations using the TEDE values only.
JPM A4 Page 3 of 5 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: l1. PERFORMANCE STEP: Locate a copy of RA-EP-02245, Protective Action.C........
Guidelines and go to Attachment 2.STANDARD:
Locate Attachment 2 of RA-EP-02245.
COMMENT: Hand the trainee a copy of RA-EP-02245.
CUE: None.SAT UNSAT 2. PERFORMANCE STEP:.C.Determine the affected subareas and enter the information in Column A.STANDARD: Using the wind direction and Attachment 3, determine the affected subareas.
For distance 0 -2 miles Subareas 1 and 12, distance 2 -5 miles Subareas 2 and 6, and 5 -10 miles Subareas 7, 8 and 9. Circle the affected subareas in column.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Enter the TEDE dose rate from the Off-site Dose.C........
Assessment Nomogram into Column B.STANDARD:
Write the correct value into Column B.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Enter the expected release duration into Column C..C.STANDARD:
Enter 2 hrs. into Column C.CUE: None.SAT UNSAT JPM A4 Page 4 of 5 5. PERFORMANCE STEP: Calculate the doses at the various distances and enter.C. the values into Column D.STANDARD: Enter 11 rem for 0.75 mile, 2.2 rem for 2 miles and 0.74 rem for 5 miles.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Identify the appropriate protective action.C. recommendation for the various distances.
STANDARD:
Compare Column D to Column E and circle in Column F,'evacuate' for 0.75 mile, 'evacuate' for 2 miles and 'No Protective Action' for 5 miles.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME Page 5 of 5 JPM A4 VERIFICATION OF COMPLETION Operator SSN License: Evaluator Date[ I RO [ I SRO [ ] ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Date Evaluator's Signature INITIAL SUBMITTAL OF THE WALKTHROUGH JPMS FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13, 1999
---JPM NEW 1B Page 10 of 19 JPM -Part B SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Restore ICS Feedwater Subsystem to Full Automatic Control INITIAL CONDITION:
Any IC 50 to 100% power; below 100% power is preferable.
ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
: 1. Place SP-7B in hand and reduce to 50% valve position.2. Place SP-6B in hand.3. Place both feedwater demand hand/auto stations in hand.MALFUNCTIONS/FAILURE TO INSERT: None.ACTION/CUES:
NOTE: Use proper 3-part communication for any necessary cues.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: NEW 1B Rev. 0 Page 11 of 20 TASK NO.: 041-005-04-0100, 041-011-01-0100, 041-013-04-0100 TASK DESCRIPTION:
Restore ICS Feedwater Subsystem to Full Automatic Control K/A
 
==REFERENCE:==
 
059-XXX-A4.10 (3.9/3.8), 059-XXX-A3.07 (3.4/3.5)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
APPLICABILITY:
[X] RO 16 minutes[ ] SRO TASK STANDARDS:
1.2.3.Feedwater startup valve hand/auto station restored to automatic control.Feedwater main valve hand/auto station restored to automatic control.Feedwater demand hand/auto stations restored to automatic control.REOUIRED MATERIALS:
DB-OP-06401, Integrated Control System Operating Procedure, Rev. 2, Ch. 4 GENERAL
 
==REFERENCES:==
 
DB-OP-06401, Integrated Control System Operating Procedure, Rev. 2, Ch. 4 INITIAL CONDITIONS:
An event has occurred that has left the following ICS hand/auto stations in hand: both feedwater loop demands, SG 1 Main Feedwater Valve, SG 1 Startup Feedwater Valve. The event has been terminated and the cause of the event has been determined and corrected.
INITIATING CUES: The Shift Supervisor has directed you to restore the ICS Feedwater Subsystem to full automatic control using DB-OP-06401, Integrated Control System Operating Procedure.(Hand a copy of DB-OP-06401 to the examinee)
JPM NEW 1B Page 12 of 19 INITIAL CONDITIONS:
An event has occurred that has left the following ICS hand/auto stations in hand: both feedwater loop demands, SG 1 Main Feedwater Valve, SG 1 Startup Feedwater Valve. The event has been terminated and the cause of the event has been determined and corrected.
INITIATING CUES: The Shift Supervisor has directed you to restore the ICS Feedwater Subsystem to full automatic control using DB-OP-06401, Integrated Control System Operating Procedure.
JPM NEW 1B Page 13 of 19 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
I START TIME: l1. PERFORMANCE STEP: Locate the correct procedure section.STANDARD:
Identifies DB-OP-06401, Section 3.5, as the correct procedure and section.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Verify HC ICS20, Reactor Demand, is in auto.STANDARD:
Red light ON and White light OFF on HC ICS20.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Review Attachment 3, FIC ICS33A and B, Feedwater Startup Valves 2 and 1.STANDARD:
Operator refers to Attachment 3.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Monitor related DAAS points.STANDARD:
Operator refers to appropriate DAAS display points.NOTE: This step is optional.CUE: None.SAT UNSAT JPM NEW 1B Page 14 of 19 JPM NEW lB Page 14 of 19 5. PERFORMANCE STEP: Slowly adjust FIC ICS32B, Feedwater Demand, until.C. feedwater demand output is slightly greater than actual Feedwater flow.STANDARD:
SG 1 feedwater demand set for [(SG 1 FW Flow/7 mpph) x 100%]+5% / -0%.COMMENT: It is also acceptable to select measured variable on FIC ICS32B and adjust output until the pointer indicates slightly above the caret.CUE: None.Current FW Flow mpph FW Demand Set %SAT UNSAT 6. PERFORMANCE STEP:.C.Slowly open SP 7B by adjusting FIC ICS33B, Feedwater Startup Valve, while adjusting FIC ICS35B, Feedwater Main Valve, to maintain constant SGblevel.STANDARD:
SP 7B at 100% valve position with constant SG level.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Depress and release AUTO on FIC ICS33B, FEEDWATER.C. STARTUP VALVE.STANDARD:
Auto button depressed and released.
Red light ON and White light OFF on FIC ICS33B.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Route to Section 3.6 STANDARD:
Identifies Section 3.6 as the next applicable procedure section.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Verify FIC ICS33B, Feedwater Startup Valve is in auto.STANDARD:
Red light ON and White light OFF on FIC ICS33B.COMMENT: This action may not be performed since FIC ICS33B was just placed in auto in Step 7.CUE: None.SAT UNSAT JPM NEW 1B Page 1S of 19 JPM NEW lB Page 15 of 19 10. PERFORMANCE STEP: Verify FIC ICS32B, Feedwater Demand, is in hand.STANDARD:
Red light OFF and White light ON on FIC ICS32B.COMMENT: This action may not be performed since FIC ICS32B position was verified in hand for Steps 5 through 7 above.CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Review Attachment 4, FIC ICS35A and B Feedwater Main Valve 2 and 1.STANDARD:
Operator refers to Attachment 4.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Monitor related DAAS points.STANDARD:
Operator refers to appropriate DAAS display points.NOTE: This step is optional.CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Adjust FIC ICS32B, Feedwater Demand, until measured C........variable on FIC ICS35B, Feedwater Main Valve is on the caret.STANDARD: COMMENT: CUE: None.Moving pointer on FIC ICS35B is positioned over the red fixed pointer (caret) within +/-5%.This action will also affect main feed pump speed.SAT UNSAT 14. PERFORMANCE STEP: Depress and release auto on FIC ICS35B, Feedwater.C. Main Valve..STANDARD:
Auto button depressed and released.
Red light ON and White light OFF on FIC ICS35B.CUE: None.SAT UNSAT JPM NEW 1B Page 16 of 19 15. PERFORMANCE STEP: Route to Section 3.8 STANDARD:
Identifies Section 3.8 as the next applicable procedure section.CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Verify FIC ICS33A&B, Feedwater Startup Valves are in auto.STANDARD:
Red light ON and White light OFF on FIC ICS33A&B.CUE: None.SAT UNSAT 17. PERFORMANCE STEP: Verify FIC ICS35A&B, Feedwater Main Valves are in auto.STANDARD:
Red light ON and White light OFF on FIC ICS35B.CUE: None.SAT UNSAT 18. PERFORMANCE STEP: Verify FIC ICS36A&B, Main Feed Pump ICS Controls are in auto.STANDARD:
Red light ON and White light OFF on FIC ICS36A&B.CUE: None. -SAT UNSAT 19. PERFORMANCE STEP: Review Attachment 6, FIC ICS32A and B Feedwater Demand 2 and 1.STANDARD:
Operator refers to Attachment 6.CUE: None.SAT UNSAT 20. PERFORMANCE STEP: Monitor related DAAS points.STANDARD:
Operator refers to appropriate DAAS display points.NOTE: This step is optional.CUE: None.SAT UNSAT JPM NEW 1B Page 17 of 19 JPM NEW lB Page 17 of 19 21. PERFORMANCE STEP: Adjust FIC ICS32B, Feedwater Demand until measured.C........
variable on FIC ICS32B is on the caret, OR measured variables are equal amounts above and below the caret on FIC ICS32B and FIC ICS32A.STANDARD:
Moving pointer on FIC ICS32B is positioned over the caret within +/-5%, OR moving pointers on FIC ICS32B and FIC ICS32A are equal amounts above and below the caret.NOTE: FIC ICS32B and FIC ICS32A may be placed in auto in either order.CUE: None.SAT UNSAT 22. PERFORMANCE STEP:.C.Adjust FIC ICS32A, Feedwater Demand until measured variable on FIC ICS32A is on the caret, OR measured variables are equal amounts above and below the caret on FIC ICS32B and FIC ICS32A.STANDARD:
Moving pointer on FIC ICS32A is positioned over the caret within +/-5%, OR moving pointers on FIC ICS32B and FIC ICS32A are equal distances above and below the caret.NOTE: FIC ICS32B and FIC ICS32A may be placed in auto in either order.CUE: None.SAT UNSAT 23 PERFORMANCE STEP:.C.IF FIC ICS32B and FIC ICS32A are equal amounts above and below the caret, THEN adjust HIC ICS30 Stm Gen Load Ratio until FIC ICS32B and FIC ICS32A measured variables are on the caret.STANDARD: CUE: None.Moving pointers on FIC ICS32B and FIC ICS32A are positioned over the caret within +/-5%.NOTE: Examinee may elect to repeat steps 21 and 22 if ICS 32A&B pointers do not end up on the caret.SAT UNSAT---- -------24. PERFORMANCE STEP:........ .......C Depress and release auto on FIC ICS32B, Feedwater Demand.STANDARD: Auto button depressed and released.
Red light ON and White light OFF on FIC ICS32B.NOTE: FIC ICS32B and FIC ICS32A may be placed in auto in either order.CUE: None.SAT UNSAT JPM NEW 1B Page 18 of 19 25. PERFORMANCE STEP: Depress and release auto on FIC ICS32A, Feedwater.C. Demand.STANDARD:
Auto button depressed and released.
Red light ON and White light OFF on FIC ICS32A.NOTE: FIC ICS32B and FIC ICS32A may be placed in auto in either order.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM NEW I Page 19 of 19 VERIFICATION OF COMPLETION Operator SSN License: Evaluator Date _[ I RO [ I SRO ( ] ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ I SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date JPM NEW 2B Page 10 of 19 JPM -Part B SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Recover From Inadvertent SFAS Incident Level 4 INITIAL CONDITION:
FPSS, any time in life ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
: 1. Insert the malfunctions listed below in the sequence listed.2. Perform Immediate Actions of DB-OP-02515, RC Pump and Motor Abnormal Operation.
: 3. Perform Immediate and Supplemental Actions of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture, Step 4.15.16.4. Place in hand and close MU 19.5. Remove malfunction LGP2C.MALFUNCTIONS/FAILURE TO INSERT:* Insert malfunction L6P2C to fail SFAS Channel 2 containment pressure transmitter high.* Insert malfunction E60A to fail 120 VAC bus Y1.ACTION/CUES:
NOTE: Use proper 3-part communication for any necessary cues.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: NEW 2B Rev. 0 Page 11 of 20 TASK NO.: 013-021-04-0100 TASK DESCRIPTION:
Recover From Inadvertent SFAS Incident Level 4 K/A
 
==REFERENCE:==
 
013-XXX-Al.02 (3.9/4.2), 013-XXX-A2.06 (3.7/4.0), 013-XXX-A4.02 (4.3/4.4)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
APPLICABILITY:
[X] RO 25 minutes[XI SRO TASK STANDARDS:
: 1. Containment Spray Pumps 1 and 2 have been stopped.2. SFAS has been reset.3. CCW to containment has been restored.4. Cooling has been restored to the control rod drive mechanisms.
REOUIRED MATERIALS:
DB-OP-06910, DB-OP-06405, Trip Recovery, Rev. 0, Ch. 7 Safety Features Actuation System Procedure, Rev. 2, Ch. 8, with Steps 3.7.1 through 3.7.3 completed and SFAS Channel 2 circled in Step 3.7.2.GENERAL
 
==REFERENCES:==
 
DB-OP-02000, DB-OP-02515, DB-OP-06405, DB-OP-06910, RPS, SFAS, SFRCS Trip or SG Tube Rupture, Rev. 5 RC Pump and Motor Abnormal Operation, Rev. 1, Ch. 4 Safety Features Actuation System Procedure, Rev. 2, Ch. 8 Trip Recovery, Rev. 0, Ch. 7 INITIAL CONDITIONS:
A sequence of events has occurred resulting in an inadvertent actuation of SFAS Incident Levels 1-4 on SFAS Containment Pressure >38.4 psia. Immediate actions for DB-OP-02515, RC Pump and Motor Abnormal Operation, have been performed, and the plant has been stabilized in accordance with DB-OP-02000.
INITIATING CUES: The Shift Supervisor has directed you to perform recovery from SFAS Incident Level 4 in accordance with DB-OP-06910, Trip Recovery, and reset SFAS Channel 2 in accordance with DB-OP-06405, Safety Features Actuation System Procedure.(Hand a copy of DB-OP-06910 to the Examinee.)
JPM NEW 2B Page 12 of 19 INITIAL CONDITIONS:
A sequence of events has occurred resulting in an inadvertent actuation of SFAS Incident Levels 1-4 on SFAS Containment Pressure >38.4 psia. Immediate actions for DB-OP-02515, RC Pump and Motor Abnormal Operation, have been performed, and the plant has been stabilized in accordance with DB-OP-02000.
INITIATING CUES: The Shift Supervisor has directed you to perform recovery from SFAS Incident Level 4 in accordance with DB-OP-06910, Trip Recovery, and reset SFAS Channel 2 in accordance with DB-OP-06405, Safety Features Actuation System Procedure.
JPM NEW 2B Page 13 of 19 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure section.STANDARD:
Identifies DB-OP-06910, Section 6.0 as the correct procedure and section.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Verify containment pressure <18.4 psia.STANDARD:
Observes SFAS containment pressure indicators.
CUE: None. I SAT UNSAT 3. PERFORMANCE STEP: Depress the block button HIS 1533A for CS Pump 1..C.STANDARD:
HIS 1533A depressed and released.
Amber Block light goes BRIGHT.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Stop CS Pump 1 using HIS 1533..C.STANDARD:
HIS 1533 placed in stop and released.
Red light goes OFF, Green light goes ON. Pump amps decrease to 0.CUE: None.SAT UNSAT 5. PERFORMANCE STEP: Depress the block button HIS 1532A for CS Pump 2..C.STANDARD:
HIS 1532A depressed and released.
Amber Block light goes BRIGHT.CUE: None.SAT UNSAT JPM NEW 2B Page 14 of 19 JPM NEW 2B Page 14 of 19 6. PERFORMANCE STEP: Stop CS Pump 2 using HIS 1532..C.STANDARD:
HIS 1532 placed in stop and released.
Red light goes OFF, Green light goes ON. Pump amps decrease to 0.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Refer to DB-OP-06405, Safety Features Actuation System Procedure, Section 3.7.STANDARD: Identifies DB-OP-06405, Section 3.7, as the correct procedure and section.COMMENT: Observe proper 3-part communication.
CUE: None.(Hand a copy of DB-OP-06405 with Steps 3.7.1 through 3.7.3 completed, and SFAS Channel 2 circled in Step 3.7.2, to the examinee after the correct section has been identified.
If the incorrect section is identified, allow the examinee to use the shelf copy.)SAT UNSAT 8. PERFORMANCE STEP: Verify EDGs are not supplying C1 or Dl buses.STANDARD:
Observes Breakers AC 101 and AD 101 open, Red lights OFF and Green lights ON.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Obtain Shift Supervisor's permission to reset an SFAS channel.STANDARD: Requests Shift Supervisor's permission to reset SFAS and inquire which channels to reset.COMMENT: Observe proper 3-part communication.
CUE: (If asked) Circle SFAS Channel 2, and state that no specific SFAS components are inoperable.
SAT UNSAT JPM NEW 2B Page 15 of 19 10. PERFORMANCE STEP: Obtain the door keys to SFAS Channels 1 through 4..C.STANDARD:
Obtains door keys for SFAS Channels 1-4.CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Verify SFAS Channel 2 is energized.
STANDARD: Observe the Red power on lights are ON at the top of SFAS Channel 2 Cabinet. Check the shutdown bypass power available Green LEDs are ON, on the SFAS shutdown bypass panel.CUE: None.SAT UNSAT 12. PERFORMANCE STEP:.C.Depress the CTMT pressure hi hi trip bistable reset pushbutton in SFAS Channel 2.STANDARD: CTMT pressure hi hi trip bistable reset button depressed and released.
Bistable trip light goes OFF.COMMENT: Examinee will verify reset all SFAS Channel 2 bistables and N/A each step of the procedure that directs resetting a bistable that has not tripped. This and the following steps only address the bistables that have tripped.CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Depress the CTMT pressure hi trip bistable reset.C. pushbutton in SFAS Channel 2.STANDARD:
CTMT pressure hi trip bistable reset button depressed and released.
Bistable trip light goes OFF.CUE: None.SAT UNSAT 14. PERFORMANCE STEP: Reset the tripped output modules in SFAS Channels.C. 2 through 4.STANDARD:
For each tripped output module in SFAS Channels 2, 3, and 4, press the reset pushbutton and observe the trip lights go OFF.CUE: None.SAT UNSAT JPM NEW 2B Page 16 of 19 JPM NEW 2B Page 16 of 19 15. PERFORMANCE STEP: Verify the SFAS cabinet doors are closed and locked.STANDARD:
Properly closes and locks all opened SFAS cabinet doors.CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Return the SFAS door keys.STANDARD:
Returns the SFAS door keys to the Control Room key cabinet.CUE: None.SAT UNSAT 17. PERFORMANCE STEP: Return to DB-OP-06910, Step 6.1.3.STANDARD:
Identifies the need to return to DB-OP-06910, Step 6.1.3.CUE: (If asked) The Shift Supervisor states that DB-OP-02000 has directed restoration of component cooling water to containment and to control rod drives.SAT UNSAT 18. PERFORMANCE STEP: Open CC 1407A, CC Wtr From CTMT Motor Operated Iso..C. Vlv., using HIS 1407A.STANDARD:
HIS 1407A open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 19. PERFORMANCE STEP: Open CC 1407B, CC Wtr From CTMT Motor Operated Iso..C. Vlv., using HIS 1407B.STANDARD:
HIS 1407B open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 20. PERFORMANCE STEP: Open CC 1411A, CC Wtr From CTMT Motor Operated Iso..C. Vlv., using HIS 1411A.STANDARD:
HIS 1411A open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT JPM NEW 2B Page 17 of 19 21. PERFORMANCE STEP: Open CC 1411B, CC Wtr From CTMT Motor Operated Iso..C. Vlv., using HIS 1411B.STANDARD:
HIS 1411B open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 22. PERFORMANCE STEP: Place HIS 1915, CRD CLNG Booster Pump 1, STANDARD:
HIS 1915 switch placed in lock out. Amber light CUE: None.in lock out.goes ON.SAT UNSAT 23. PERFORMANCE STEP: Place HIS 1924, CRD CLNG Booster Pump 2, STANDARD:
HIS 1924 switch placed in lock out. Amber light CUE: None.in lock out.goes ON.SAT UNSAT 24. PERFORMANCE STEP: Open CC 1328, CCW to CRD Clng Booster Pump 1 Suct.,.C........
using HIS 1328.STANDARD:
HIS 1328 open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 25. PERFORMANCE STEP: Open CC 1338, CCW to CRD Clng Booster Pump 2 Suct.,.C........
using HIS 1338.STANDARD:
HIS 1338 open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 26. PERFORMANCE STEP: Open CC 1567A, CCW to CRDM, using HIS 1567A..C.STANDARD:
HIS 1567A open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT JPM NEW 2B Page 18 of 19 27. PERFORMANCE STEP: Open CC 1567B, CCW to CRDM, using HIS 1567B..C.STANDARD:
HIS 1567B open button depressed and released.
Green light goes OFF, and Red light goes ON.CUE: None.SAT UNSAT 28. PERFORMANCE STEP: Start the preferred CRD booster pump by placing the.C........
control switch in auto.STANDARD:
HIS 1915 placed in auto. Amber light goes OFF,then Green light goes OFF, and Red light goes ON.NOTE: Critical only if Steps 22 and 23 were performed.
CUE: None.SAT UNSAT 29. PERFORMANCE STEP: Place the standby CRD booster pump control switch in auto.STANDARD:
HIS 1924 placed in auto. Amber light goes OFF.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM NEW 2 Page 19 of 19 VERIFICATION OF COMPLETION Operator SSN License: Evaluator Date_[ I RO [ ] SRO [ I ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: NEW 03-1 Rev. 0 Page 1 of 19 TASK NO.: 062-028-01-0100 TASK DESCRIPTION:
Perform a Local Dead 13.8 KV Bus Transfer Note: Use JPM NEW 03-1 if Train 2 is Train 1 is protected.
protected; use JPM NEW 03-2 if K/A
 
==REFERENCE:==
 
062-XXX, A2.15 (2.8/3.2), A4.07 (3.1/3.1)APPLICABLE METHOD OF TESTING: Simulate In-Plant Alternate procedure TIME FOR COMPLETION:
20 minutes APPLICABILITY:
[X] RO[X] SRO TASK STANDARDS:
: 1. Recognize out of phase condition of bus sources.2. Transfer Bus A source to Startup Transformer 02.REOUIRED MATERIALS:
DB-OP-06314, 13.8 KV Bus Switching Procedure, Revision 01 GENERAL
 
==REFERENCES:==
 
DB-OP-06314, 13.8 KV Bus Switching Procedure, Revision 01 INITIAL CONDITIONS:
An event has occurred that resulted in evacuation of the Control Room.Local control has been established at the auxiliary shutdown panel and the plant has been stabilized.
EDG 1 is supplying power to 4160 VAC Buses C1 and C2. EDG 2 is supplying power to 4160 VAC Buses Dl and D2.All load breakers have been opened on A and B buses.13.8 KV Bus A has been reenergized from Startup Transformer 01.Bus B has been reenergized from Startup Transformer 02.13.8 KV As a result of unusual indications on Startup Transformer 01, Startup Transformer 01 must be deenergized.
In order to permit Startup Transformer 01 to be deenergized, 13.8 KV Bus A must be transferred to Startup Transformer
: 02.
JPM NEW 3-1 Page 2 of 19 INITIATING CUES: You have been directed to perform a local live bus transfer of 13.8 KV Bus A to Startup Transformer 02 using DB-OP-06314, 13.8 KV Bus Switching Procedure.(Hand a copy of DB-OP-06314 to the examinee.)
JPM NEW 3-1 Page 3 of 19 INITIAL CONDITIONS:
An event has occurred that resulted in evacuation of the Control Room.Local control has been established at the auxiliary shutdown panel and the plant has been stabilized.
EDG 1 is supplying power to 4160 VAC Buses C1 and C2. EDG 2 is supplying power to 4160 VAC Buses Dl and D2.All load breakers have been opened on A and B buses.13.8 KV Bus A has been reenergized from Startup Transformer
: 01. 13.8 KV Bus B has been reenergized from Startup Transformer 02.As a result of unusual indications on Startup Transformer 01, Startup Transformer 01 must be deenergized.
In order to permit Startup Transformer 01 to be deenergized, 13.8 KV Bus A must be transferred to Startup Transformer 02.INITIATING CUES: You have been directed to perform a local live bus transfer of 13.8 KV Bus A to Startup Transformer 02 using DB-OP-06314, 13.8. KV Bus Switching Procedure.
JPM NEW 3-1 Page 4 of 19 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet these standards for this item constitutes failure.assumed unless denoted in the "Comments".
any one of Sequence is START TIME: 1. PERFORMANCE STEP: Determine the correct procedure section.STANDARD:
Determine that Section 4.1 is the correct section.CUE: All prerequisites are complete.(If asked) The Shift Supervisor directs you to use source breaker HX02A.SAT UNSAT 2. PERFORMANCE STEP: Verify 25SWA/LOCAL Synchro Check Selector in OFF.STANDARD:
Observe the position of 25SWA/LOCAL Synchro Check Selector to be OFF (and place in OFF if not already in that position).
CUE: 25SWA/LOCAL Synchro Check Selector indicates OFF.SAT UNSAT 3. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch A Bus positioned the same as HS 6294 or as directed by the Shift Supervisor.
STANDARD: Observe the position of the 10/LOCAL Reserve Source Selector Switch A Bus.CUE: 10/LOCAL Reserve Source Selector Switch A Bus indicates X02.(If asked) The Shift Supervisor directs you to leave the local Reserve Source Selector Switch in the X02 position.SAT UNSAT 4. PERFORMANCE STEP: Place DSA/LOCAL in LOCAL..C.STANDARD:
Place the DSA/LOCAL switch on C3610 to the LOCAL position.CUE: DSA/LOCAL switch has been placed in LOCAL.SAT UNSAT 5. PERFORMANCE STEP: Place the emergency control transfer switch for.C........
HX02A in LOCAL.STANDARD: Place the emergency control transfer switch for HX02A in LOCAL on Cubicle 4 of A bus.CUE: HX02A emergency control transfer switch has been placed in LOCAL.SAT UNSAT JPM NEW 3-1 Page 5 of 19 JPM NEW 3-1 Page 5 of 19 6. PERFORMANCE STEP: Place the emergency control transfer switch for HXllA in LOCAL.STANDARD: Place the emergency control transfer switch for HXllA in LOCAL on Cubicle 9 of A Bus.CUE: HXl1A emergency control transfer switch has been placed in LOCAL.SAT UNSAT 7. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HXO1A in LOCAL.STANDARD: Place the emergency control transfer switch for HXO1A in LOCAL on Cubicle 11 of A Bus.CUE: HXO1A Emergency Control Transfer Switch has been placed in LOCAL.STt SAT UNSAT 8. PERFORMANCE STEP: Visually check Synchro Check Relay 25 contacts open.STANDARD:
Observe the condition of Synchro Check Relay 25 contacts (cubicle 5 upper left window.)CUE: Synchro Check Relay 25 contacts indicate open.COMMENT: A safe stool for observing the relay 25 contact position is located in the NE corner of the room behind 4160 VAC bus C1.Extreme caution must be used when manipulating the stool near switchgear cabinets to prevent bumping cabinet doors and causing relay actuations.
SAT UNSAT 9. PERFORMANCE STEP:.C.Turn 25SWA/LOCAL, Synchro Check Selector to the desired source and wait 15 seconds.STANDARD: Place 25SWA/LOCAL, Synchro Check Selector to the X02 position and wait 15 seconds for the Synchro Check Relay 25 contacts to respond.COMMENT: If sources are out of phase, the relay will not respond.CUE: Switch 25SWA/LOCAL has been rotated to the X02 position.
Fifteen seconds have elapsed. Synchro Check Relay contacts indicate open.SAT UNSAT JPM NEW 3-1 Page 6 of 19 JPM NEW 3-1 Page 6 of 19 10. PERFORMANCE STEP:.C.Notify the Shift Supervisor that the synchro check relay contacts did not close.STANDARD:
Notify the Shift Supervisor of relay response.CUE: Shift Supervisor acknowledges that the synchro check relay contacts did not close and directs you to perform a dead bus transfer.SAT UNSAT 11. PERFORMANCE STEP: Route to Section 4.3, Local Dead Bus A Transfer..C.STANDARD:
Determine that Section 4.3, Local Dead Bus A Transfer, is the correct section.COMMENT: Repeat initiating cues as necessary for procedure Steps 4.3.1 and 4.3.2 CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Verify 25SWA/LOCAL Synchro Check Selector in OFF.STANDARD:
Observe the position of 25SWA/LOCAL Synchro Check Selector to be OFF (and place in OFF if not already in that position).
CUE: 25SWA/LOCAL Synchro Check Selector indicates X02. 25SWA/LOCAL Synchro Check Selector has been rotated to OFF.SAT UNSAT 13. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch A Bus positioned the same as HS 6294 or as directed by the Shift Supervisor.
STANDARD: Observe the position of the 10/LOCAL Reserve Source Selector Switch A Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section.CUE: 10/LOCAL Reserve Source Selector Switch A Bus indicates X02.(If asked) the Shift Supervisor directs you to leave the local Reserve Source Selector Switch in the X02 position.SAT UNSAT JPM NEW 3-1 Page 7 of 19 JPM NEW 3-1 Page 7 of 19 14. PERFORMANCE STEP: Place DSA/LOCAL in LOCAL..C.STANDARD:
Place the DSA/LOCAL switch on C3610 to the LOCAL position.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: DSA/LOCAL switch [is/has been placed] in LOCAL.SAT UNSAT 15. PERFORMANCE STEP: Place the emergency control transfer switch for.C........
HX02A in LOCAL.STANDARD: Place the emergency control transfer switch for HX02A in LOCAL on Cubicle 4 of A Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
I CUE: HX02A emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT 16. PERFORMANCE STEP: Place the emergency control transfer switch for HXllA in LOCAL.STANDARD: Place the emergency control transfer switch for HXllA in LOCAL on Cubicle 9 of A Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section.CUE: HX11A emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT 17. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HX0lA in LOCAL.STANDARD: Place the emergency control transfer switch for HXOIA in LOCAL on cubicle 11 of A Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: HXOlA emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT JPM NEW 3-1 Page 8 of 19 18. PERFORMANCE STEP: Verify the following equipment out of service: RCP 1-1, RCP 2-2, Circ. Water Pump 1 and Circ. Water Pump 3.STANDARD: Verify open indication on the breakers for RCP 1-1, RCP 2-2, Circ. Water Pump 1 and Circ. Water Pump 3.COMMENT: Trainee may not perform this step due to initial conditions.
CUE: Green Green Green Water Green Water light is LIT, Red light is OFF on HA01, breaker light is LIT, Red light is OFF on HA03, breaker light is LIT, Red light is OFF on HA08, breaker Pump 1.light is LIT, Red light is OFF on HA12, breaker Pump 3.for RCP 1-1.for RCP 2-2.for Circ.for Circ.SAT UNSAT 19. PERFORMANCE STEP: Trip the following load breakers:
HAAC, HAAE4, HAAE2 and HAAE3.STANDARD: Verify open indication on Breakers HAAC, HAAE4, HAAE2 and HAAE3.COMMENT: Trainee may not perform this step due to initial conditions.
CUE: Green light is LIT, Red light is OFF on HAAC.Green light is LIT, Red light is OFF on HAAE4.Green light is LIT, Red light is OFF on HAAE2.Green light is LIT, Red light is OFF on HAAE3.SAT UNSAT 20. PERFORMANCE STEP: Open Source Breaker HX01A..C.STANDARD:
Place handswitch on Cubicle 11 of Bus A (HXOlA) to TRIP, and release.CUE: Handswitch has been placed in TRIP and released.
Green light LIGHTS and Red light goes OFF.SAT UNSAT 21. PERFORMANCE STEP:.C.Turn 25SWA/LOCAL, Synchro Check Selector to the desired source.STANDARD: Place 25SWA/LOCAL, Synchro Check Selector to the X02 position.COMMENT: No check of synchro check relay contact position is required for dead bus transfer.CUE: 25SWA/LOCAL has been placed in the X02 position.SAT UNSAT JPM NEW 3-1 Page 9 of 19 22. PERFORMANCE STEP: Close Source Breaker HX02A..C.STANDARD:
Place handswitch on cubicle 4 of Bus A (HX02A) to CLOSE and release.CUE: Handswitch has been placed to CLOSE and released.
RED light LIGHTS and Green light goes OFF.SAT UNSAT 23. PERFORMANCE STEP: Turn 25SWA/LOCAL, Synchro Check Selector to OFF.STANDARD:
Place 25SWA/LOCAL, Synchro Check Selector to the OFF position.CUE: 25SWA/LOCAL has been placed in the OFF position.SAT UNSAT 24. PERFORMANCE STEP: Verify normal system voltage on EI 6256, A Bus Kilovolts.
STANDARD:
Observe 13.8 KV Bus A indicates approximately 13.8 KV.COMMENT: Since the Control Room is unoccupied, the examinee will either read the voltage on the local meter or ask the Shift Supervisor for guidance.
Either action is acceptable.
CUE: No one is available to read EI 6256. (If asked) The Shift Supervisor directs you to use the local indicator to check bus voltage. The phase select switch has been rotated [through all three phases] and [each phase] indicates approximately 13.8 Kilovolts.
SAT UNSAT 25. PERFORMANCE STEP: Turn 10/LOCAL, Reserve Source Selector Switch A Bus to the X01 position.STANDARD:
Place 10/LOCAL, Reserve Source Selector Switch Bus A to the X01 position.COMMENT: Since Startup Transformer 01 will be deenergized, it is acceptable for the examinee to omit this step.CUE: (If performed) 10/LOCAL has been placed in the X01 position.SAT UNSAT TERMINATING CUES: This JPM is complete.COMMENT: Please ensure the stool, if used, is carefully returned to its storage location and secured.END TIME DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: NEW 03-2 Rev. 0 Page 11 of 19 TASK NO.: 062-028-01-0100 TASK DESCRIPTION:
Perform a Local Dead 13.8 KV Bus Transfer Note: Use JPM NEW 03-1 if Train 2 is Train 1 is protected.
protected; use JPM NEW 03-2 if K/A
 
==REFERENCE:==
 
062-XXX, A2.15 (2.8/3.2), A4.07 (3.1/3.1)APPLICABLE METHOD OF TESTING: Simulate In-Plant Alternate procedure TIME FOR COMPLETION:
APPLICABILITY:
[XI RO TASK STANDARDS:
20 minutes[XJ SRO 1. Recognize out of phase condition of bus sources.2. Transfer Bus B source to Startup Transformer 01.REQUIRED MATERIALS:
DB-OP-06314, 13.8 KV Bus Switching Procedure, Revision 01 GENERAL
 
==REFERENCES:==
 
DB-OP-06314, 13.8 KV Bus Switching Procedure, Revision 01 INITIAL CONDITIONS:
An event has occurred that resulted in evacuation of the Control Room.Local control has been established at the auxiliary shutdown panel and the plant has been stabilized.
EDG 1 is supplying power to 4160 VAC Buses C1 and C2. EDG 2 is supplying power to 4160 VAC Buses Dl and D2.All load breakers have been opened on A and B buses.13.8 KV Bus A has been reenergized from Startup Transformer 01.Bus B has been reenergized from Startup Transformer 02.13.8 KV As a result of unusual indications on Startup Transformer 02, Startup Transformer 02 must be deenergized.
In order to permit Startup Transformer 02 to be deenergized, 13.8 KV Bus B must be transferred to Startup Transformer
: 01.
JPM NEW 3-2 INITIATING CUES: Page 11 of 19 You have been directed to perform a local live bus transfer of 13.8 KV Bus B to Startup Transformer 01 using DB-OP-06314, 13.8 KV Bus Switching Procedure.(Hand a copy of DB-OP-06314 to the examinee.)
JPM NEW 3-2 Page 12 of 19 INITIAL CONDITIONS:
An event has occurred that resulted in evacuation of the Control Room.Local control has been established at the auxiliary shutdown panel and the plant has been stabilized.
EDG 1 is supplying power to 4160 VAC Buses C1 and C2. EDG 2 is supplying power to 4160 VAC Buses DI and D2.All load breakers have been opened on A and B buses.13.8 KV Bus A has been reenergized from Startup Transformer
: 01. 13.8 KV Bus B has been reenergized from Startup Transformer 02.As a result of unusual indications on Startup Transformer 02, Startup Transformer 02 must be deenergized.
In order to permit Startup Transformer 02 to be deenergized, 13.8 KV Bus B must be transferred to Startup Transformer 01.INITIATING CUES: You have been directed to perform a local live bus transfer of 13.8 KV Bus B to Startup Transformer 01 using DB-OP-06314, 13.8 KV Bus Switching Procedure.
JPM NEW 3-2 Page 13 of 19 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
I START TIME: I 1. PERFORMANCE STEP: Determine the correct procedure section.STANDARD:
Determine that Section 4.2 is the correct section.CUE: All prerequisites are complete. (If asked) The Shift Supervisor desires you to use source breaker HXOIB.SAT UNSAT 2. PERFORMANCE STEP: Verify 25SWB/LOCAL Synchro Check Selector in OFF.STANDARD:
Observe the position of 25SWB/LOCAL Synchro-check Selector to be OFF (and place in OFF if not already in that position).
CUE: 25SWB/LOCAL Synchro Check Selector indicates OFF.SAT UNSAT 3. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch B Bus positioned the same as HS 6295 or as directed by the Shift Supervisor.
STANDARD: Observe the position of the 10/LOCAL Reserve Source Selector Switch B Bus.CUE: 10/LOCAL Reserve Source Selector Switch B Bus indicates X01. (If asked) The Shift Supervisor directs you to leave the local Reserve Source Selector Switch in the XO0 position.SAT UNSAT 4. PERFORMANCE STEP: Place DSB/LOCAL in LOCAL..C.STANDARD:
Place the DSB/LOCAL switch on C3611 to the LOCAL position.CUE: DSB/LOCAL switch has been placed in LOCAL.SAT UNSAT 5. PERFORMANCE STEP: Place the emergency control transfer switch for.C........
HX01B in LOCAL.STANDARD: Place the emergency control transfer switch for HXO1B in LOCAL on Cubicle 11 of B Bus.CUE: HXOlB emergency control transfer switch has been placed in LOCAL.SAT UNSAT JPM NEW 3-2 Page 14 of 19 JPM NEW 3-2 Page 14 of 19 6. PERFORMANCE STEP: Place the emergency control transfer switch for HXllB in LOCAL.STANDARD: Place the emergency control transfer switch for HXllB in LOCAL on Cubicle 9 of B Bus.CUE: HX11B emergency control transfer switch has been placed in LOCAL.SAT UNSAT 7. PERFORMANCE STEP:.C.Place the emergency control transfer Switch for HX02B in LOCAL.STANDARD: Place the emergency control transfer switch for HX02B in LOCAL on Cubicle 4 of B Bus.CUE: HX02B emergency control transfer switch has been placed in LOCAL.SAT UNSAT 8. PERFORMANCE STEP: Visually check Synchro Check Relay 25 contacts open.STANDARD: Observe the condition of Synchro Check Relay 25 contacts (Cubicle 5 upper left window.)COMMENT: A safe stool for observing the Relay 25 contact position is located in the NE corner of the room north of 4160 VAC Bus Dl. Extreme caution must be used when manipulating the stool near switchgear cabinets to prevent bumping cabinet doors and causing relay actuations.
CUE: Synchro Check Relay 25 contacts indicate open.SAT UNSAT 9. PERFORMANCE STEP:.C.Turn 25SWB/LOCAL, Synchro Check Selector to the desired source and wait 15 seconds.STANDARD: Place 25SWB/LOCAL, Synchro Check Selector to the X01 position and wait 15 seconds for the Synchro Check Relay 25 contacts to respond.COMMENT: If sources are out of phase, the relay will not respond.CUE: Switch 25SWB/LOCAL has been placed in X01. Fifteen seconds have elapsed. Synchro check relay contacts indicate open.SAT UNSAT JPM NEW 3-2 Page 15 of 19 JPM NEW 3-2 Page 15 of 19 10. PERFORMANCE STEP: Notify the Shift Supervisor that the synchro check.C. selector relay contacts did not close.STANDARD:
Notify the Shift Supervisor of relay response.CUE: Shift Supervisor acknowledges that the synchro check relay contacts did not close and directs you to perform a dead bus transfer.SAT UNSAT 11. PERFORMANCE STEP: Route to Section 4.4, Local Dead Bus B Transfer.STANDARD: Determine that Section 4.4, Local Dead Bus B Transfer, is the correct section.COMMENT: Repeat initiating cues as necessary for procedure Steps 4.4.1 and 4.4.2 CUE: None.--SAT UNSAT 12. PERFORMANCE STEP: Verify 25SWB/LOCAL Synchro Check Selector in OFF.STANDARD:
observe the position of 25SWB/LOCAL Synchro Check Selector to be OFF (and place in OFF if not already in that position).
CUE: 25SWB/LOCAL Synchro Check Selector indicates X01. 25SWB/LOCAL Synchro Check Relay has been rotated to OFF.SAT UNSAT 13. PERFORMANCE STEP: Verify 10/LOCAL, Reserve Source Selector Switch B Bus positioned the same as HS 6295 or as directed by the Shift Supervisor.
STANDARD: Observe the position of the 10/LOCAL Reserve Source Selector Switch B Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section.CUE: 10/LOCAL Reserve Source Selector Switch B Bus indicates X01.(If asked) the Shift Supervisor directs you to leave the local Reserve Source Selector Switch in the XO position.SAT UNSAT JPM NEW 3-2 Page 16 of 19 JPM NEW 3-2 Page 16 of 19 14. PERFORMANCE STEP: Place DSB/LOCAL in LOCAL..C.STANDARD:
Place the DSB/LOCAL switch on C3611 to the LOCAL position.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: DSB/LOCAL switch [is/has been placed] in LOCAL.SAT UNSAT 15. PERFORMANCE STEP: Place the emergency control transfer switch for.C........
HXOIB in LOCAL.STANDARD: Place the emergency control transfer switch for HXO1B in LOCAL on Cubicle 11 of B Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: HXO1B emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT 16. PERFORMANCE STEP: Place the emergency control transfer switch for HXllB in LOCAL.STANDARD: Place the emergency control transfer switch for HXllB in LOCAL on Cubicle 9 of B Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section.CUE: HX11B emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT 17. PERFORMANCE STEP:.C.Place the emergency control transfer switch for HX02B in LOCAL.STANDARD: Place the emergency control transfer switch for HX02B in LOCAL on Cubicle 4 of B Bus.COMMENT: Trainee may not repeat this step due to being performed for previous section. This step is critical only if it was not previously performed.
CUE: HX02B emergency control transfer switch [is/has been placed] in LOCAL.SAT UNSAT JPM NEW 3-2 Page 17 of 19 JPM NEW 3-2 Page 17 of 19 18. PERFORMANCE STEP: Verify the following equipment out of service: RCP 1-2, RCP 2-1, Circ. Water Pump 2 and Circ.Water Pump 4.STANDARD: Verify open indication on the breakers for RCP 1-2, RCP 2-1, Circ. Water Pump 2 and Circ. Water Pump 4.COMMENT: Trainee may not perform this step due to initial conditions.
CUE: Green Green Green Water Green Water light is LIT, Red light is OFF on HAO1, breaker for RCP 2-1.light is LIT, Red light is OFF on HAO3, breaker for RCP 1-2.light is LIT, Red light is OFF on HAO8, breaker for Circ.Pump 1.light is LIT, Red light is OFF on HA12, breaker for Circ.Pump 3.SAT UNSAT 19. PERFORMANCE STEP: Trip the following load breakers:
HBBD, HBBF4, HBBF2 and HBBF3.STANDARD: Verify open indication on the breakers HBBC, HBBF4, HBBF2 and HBBF3.COMMENT: Trainee may not perform this step due to initial conditions.
CUE: Green light is LIT, Red light is OFF on HAAC.Green light is LIT, Red light is OFF on HAAE4.Green light is LIT, Red light is OFF on HAAE2.Green light is LIT, Red light is OFF on HAAE3.SAT UNSAT 20. PERFORMANCE STEP: Open source breaker HX02B..C.STANDARD:
Place handswitch on Cubicle 4 of Bus B (HX02B) to TRIP, and release.CUE: Handswitch HX02B has been placed in TRIP and released.
Green light LIGHTS and Red light goes OFF.SAT UNSAT 21. PERFORMANCE STEP: Turn 25SWB/LOCAL, Synchro Check Selector to the.C........
desired source.STANDARD: Place 25SWB/LOCAL, Synchro Check Selector to the X01 position.COMMENT: No check of synchro check relay contact position is required for dead bus transfer.CUE: 25SWB/LOCAL has been placed in the X01 position.SAT UNSAT JPM NEW 3-2 Page 18 of 19 JPM NEW 3-2 Page 18 of 19 22. PERFORMANCE STEP: Close Source Breaker HXO1B..C.STANDARD:
Place handswitch on Cubicle 11 of Bus B (HX01B) to CLOSE and release.CUE: Handswitch HXOiB has been placed in CLOSE and released.
RED light LIGHTS and Green light goes OFF.SAT UNSAT 23. PERFORMANCE STEP: Turn 25SWB/LOCAL, Synchro Check Selector to OFF.STANDARD:
Place 25SWB/LOCAL, Synchro Check Selector to the OFF position.CUE: 25SWB/LOCAL has been placed in the OFF position.SAT UNSAT 24. PERFORMANCE STEP: Verify normal system voltage on EI 6257, B Bus Kilovolts.
STANDARD:
Observe 13.8 KV Bus B indicates approximately 13.8 KV.COMMENT: Since the Control Room is unoccupied, the examinee will either read the voltage on the local meter or ask the Shift Supervisor for guidance.
Either action is acceptable.
It is not necessary to check voltage on all three phases.CUE: No one is available to read El 6257. (If asked) The Shift Supervisor directs you to use the local indicator to check bus voltage. The phase select switch has been rotated [through all three phases] and [each phase] indicates approximately 13.8 Kilovolts.
SAT UNSAT 25. PERFORMANCE STEP: Turn 10/LOCAL, Reserve Source Selector Switch B Bus to the X02 position.STANDARD:
Place 10/LOCAL, Reserve Source Selector Switch Bus B to the X02 position.COMMENT: Since Startup Transformer 02 will be deenergized, it is acceptable for the examinee to omit this step.CUE: (If performed) 10/LOCAL has been placed in the X02 position.SAT UNSAT TERMINATING CUES: This JPM is complete.COMMENT: Please ensure the stool, if used, is carefully returned to its storage location and secured.END TIME JPM NEW 3 Page 19 of 19 Operator SSN License: VERIFICATION OF COMPLETION Evaluator Date[ ] RO [ I SRO [ ] ONL Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Date Evaluator's Signature JPM No. 02C Page 12 of 17 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Initiate a Long Term Boron Dilution Flowpath INITIAL CONDITION:
100 percent power anytime in life. Insert a large break LOCA, deposit TVHH0101 to 1.0, then allow it to run until RCS pressure is < 200 psig.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
Transfer LPI suction to CTMT Emergency Sump.Close breakers for DH11 (TCB11152) and DH12 (TCB11252).
MALFUNCTIONS/FAILURE TO INSERT: Close DH10 and DH26 ACTION/CUES:
: 1. Step 8: Flow on FI 4999 is 50 gpm.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 02C Rev. 07 Page 13 of 17 TASK NO.: 000-058-05-0100 TASK DESCRIPTION:
Initiate a Long Term Boron Dilution Flowpath K/A
 
==REFERENCE:==
 
006-XXX, A4.02 4.0/3.8, GEN-XXX-2.1.30, 3.9/3.4 APPLICABLE METHOD OF TESTING: Actual performance Simulator Control Room Alternate path TIME FOR COMPLETION:
APPLICABILITY:
[X] RO TASK STANDARDS:
10 minutes[XI SRO Establish an auxiliary flowpath through the core by creating another discharge path through DH 2735, 2736.REQUIRED MATERIALS:
DB-OP-02000, Rev. 05, RPS, SFAS, SFRCS or SG Tube Rupture GENERAL
 
==REFERENCES:==
 
DB-OP-02000, Rev. 05, RPS, SFAS, SFRCS or SG Tube Rupture INITIAL CONDITIONS:
The plant has experienced a large break LOCA. Suction for the LPI pumps has been swapped to the emergency sump. Both LPI pumps are in service. The breakers for DH11 and DH12 are closed.INITIATING CUES: The Shift Supervisor has obtained the TSC concurrance and directs you to line up for long term boron dilution using the decay heat drop line (preferred method) in accordance with DB-OP-02000, Step 10.14.
JPM No. 02C Page 14 of 17 INITIAL CONDITIONS:
The plant has experienced a large break LOCA. Suction for the LPI pumps has been swapped to the emergency sump. Both LPI pumps are in service. The breakers for DHll and DH12 are closed.INITIATING CUES: The Shift Supervisor has obtained the TSC concurrance and directs you to line up for long term boron dilution using the decay heat drop line (preferred method) in accordance with DB-OP-02000, step 10.14.
JPM No. 02C Page 15 of 17 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is NOT required unless denoted in the "Comments".
START TIME: _ __1. PERFORMANCE STEP: Locate the correct procedure section.STANDARD:
Identifies DB-OP-02000, RPS, SFAS, SFRCS or SG Tube Rupture, Section 10 as correct section.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Open DH 11, RCS to DH System Iso. Valve.STANDARD:
Apply control power by pressing ON at HIS llA.Press OPEN on HIS 11.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Open DH 12, RCS to DH System Iso. Valve.STANDARD:
Apply control power by pressing ON at HIS 12A.Press OPEN on HIS 12.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Verify a minimum flow of 40 gpm.STANDARD:
Visual check via FI 4908 and FI 4909.CUE: (If asked), The Shift Supervisor directs you to continue with the procedure while he looks into the reason for the lack of flow.SAT UNSAT 5. PERFORMANCE STEP: Close DH-li and DH-12..C.STANDARD:
Press CLOSE on HIS DH 11 and HIS DH 12.CUE: None.SAT UNSAT JPM No. 02C Page 16 of 17 6. PERFORMANCE STEP: Close RC-10, Pzr. Spray Iso. Valve.STANDARD:
Press CLOSE on HIS RC 10.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Open DH-2736, DH Aux. Spray Throttle Valve and.C. DH-2735, DH Aux. Spray Stop Valve.STANDARD:
Press OPEN on HIS 2735 and HIS 2736.NOTE: DH-2736 is a throttle valve. The OPEN button will have to be held until the valve is fully open.CUE: (If asked) You have permission for locked valves.SAT UNSAT 8. PERFORMANCE STEP: Verify minimum flow of 42 gpm.STANDARD:
Direct EO to report flow as read on FI 4999.COMMENT: Have Trainee utilize EO for this step.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 02 Page 17 of 17 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 27 Rev. 09 Page 1 of 6 TASK NO.: 076-004-04-0100 TASK DESCRIPTION:
Use Circ Water to Supply Service Water Primary Loads K/A
 
==REFERENCE:==
 
000-062, GEN.06 (3.4/3.6)APPLICABLE METHOD OF TESTING: Simulate performance In-plant TIME FOR COMPLETION:
13 minutes APPLICABILITY:
[X] RO [X] SRO TASK STANDARDS:
Circ. Water System supplying SW primary loads.REOUIRED MATERIALS:
DB-OP-02511, Loss of Service Water Pumps/System, Revision 01, C-4 GENERAL
 
==REFERENCES:==
 
DB-OP-02511, Loss of Service Water Pumps/System, Revision 01, C-4 INITIAL CONDITIONS:
The plant is in Mode 3 with a loss of all service water in progress.INITIATING CUES: The Shift Supervisor directs you to line up circulating water to supply Loop 2 primary loads, per Attachment 7 of DB-OP-02511.(Hand examinee a copy of DB-OP-02511.)
JPM No. 27 Page 2 of 6 INITIAL CONDITIONS:
The plant is in Mode 3, with a loss of all service water in progress.INITIATING CUES: The Shift Supervisor directs you to line up circulating water to supply Loop 2 primary loads, per Attachment 7 of DB-OP-02511.
JPM No. 27 Page 3 of 6 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: l 1. PERFORMANCE STEP: Verify CT 2955, TPCW HX SUPPLY FROM CIRC WTR, is OPEN.STANDARD:
Verify valve position by pointing (locally) or requesting indicating light from the Control Room.CUE: CT 2955 local position indicator is pointing to OPEN.HIS 2955 Red light is LIT.NV 2955 Red light is LIT (if asked).SAT UNSAT 2. PERFORMANCE STEP: Verify CT 56, CIRCULATING WATER SUPPLY TO TURBINE PLANT COOLING WATER HEAT EXCHANGER STOP VALVE, is OPEN.STANDARD:
Verify valve position by local position indicator.
CUE: CT 56 valve indicator is pointing to "0".SAT UNSAT 3. PERFORMANCE STEP: Isolate service water to secondary loads.STANDARD:
Close SW 155, SW TO BACKWASH RECEIVER TANK SUMP PUMP DISCHARGE ISOLATION.
CUE: SW 155 has been rotated clockwise and the valve stem is IN.SAT UNSAT JPM No. 27 Page 4 of 6 JPM No. 27 Page 4 of 6 4. PERFORMANCE STEP: Isolate service water to secondary loads..C.STANDARD:
Close the following valves: SW 51, TPCW HEAT EXCHANGER 1 INLET ISOLATION VALVE.SW 52, TPCW HEAT EXCHANGER 2 INLET ISOLATION VALVE.SW 53, TPCW HEAT EXCHANGER 3 INLET ISOLATION VALVE.CUE: SW 51 has been rotated clockwise and the valve position indicator moves from vertical to horizontal.
SW 52 has been rotated clockwise and the valve position indicator moves from vertical to horizontal.
SW 53 has been rotated clockwise and the valve position indicator moves from vertical to horizontal.
SAT UNSAT 5. PERFORMANCE STEP: Isolate service water to secondary loads.STANDARD: Close AS 283, SERVICE WATER CONTROL VALVE ISOLATION VALVE (Blowdown Mix Condenser).
COMMENT: AS 283 is located on the 585'level, Aux. Boiler Room, south wall.CUE: AS 283 has been rotated clockwise and the valve stem is IN.SAT UNSAT 6. PERFORMANCE STEP: Open Breaker BF 1277..C.STANDARD:
Take breaker handle to OFF/TRIPPED position.CUE: BF 1277 breaker handle has been pushed down and indicates OFF/TRIPPED.
SAT UNSAT JPM No. 27 Page 5 of 6 7. PERFORMANCE STEP: Open SW 1395, TPCW HEAT EXCHANGE INLET HEADER ISO.C. VALVE.STANDARD: Engage handwheel, turn counterclockwise on the handwheel for SW 1395.COMMENTS:
Indicating lights off because breaker has just been opened.CUE: SW 1395 handwheel clutch has been DEPRESSED, the handwheel has been turned counterclockwise, and the SW 1395 position indicator is pointing up.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 27 Page 6 of 6 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
/Evaluator's Signature Date JPM No. 44B Page 6 of 12 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Loss of Instrument Air Actions from the Control Room.INITIAL CONDITION:
100% any time in life.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
Station Air Compressor 2 running.MALFUNCTIONS/FAILURE TO INSERT: Leak on Instrument Air System. TVKF0701/ramp to 0.0376 over 4 minutes.ACTION/CUES:
: 1. Step 6: SA6445 is closed.2. Step 6: SA236 is closed.3. Step 7: Checking for air leaks.4. Step 8: SA18 and SA20 closed, TAKFO110/0.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 44B Rev. 08 Page 7 of 12 TASK NO.: 078-009-04-0100 TASK DESCRIPTION:
Loss of Instrument Air Actions from the Control Room K/A
 
==REFERENCE:==
 
000-065-EA1.04 (3.5/3.4), 000-065-EA2.06 (3.6/4.2), 000-065-GEN.06 (3.1/3.3)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
5 minutes APPLICABILITY:
[X] RO [X] SRO TASK STANDARDS:
Trip the reactor and actuate SFRCS when air pressure is 75 psig.REQUIRED MATERIALS:
DB-OP-02528, Loss of Instrument Air Abnormal Procedure, Revision 02, C-6 GENERAL
 
==REFERENCES:==
 
DB-OP-02528, Loss of Instrument Air Abnormal Procedure, Revision 02, C-6 INITIAL CONDITIONS:
The plant is operating in Mode 1. All systems in a normal line up.INITIATING CUES: The following annunciator alarms are received:-STA AIR HDR PRESS LO (9-3-E)-INSTR AIR HDR PRESS LO (9-1-F)
JPM No. 44B INITIAL CONDITIONS:
The plant is in Mode 1. All systems in a normal line up.Page 8 of 12 INITIATING CUES: The following annunciator alarms are received:-STA AIR HDR PRESS LO (9-3-E)-INSTR AIR HDR PRESS LO (9-1-F)
JPM No. 44B Page 9 of 12 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure.
STANDARD:
Identifies DB-OP-02528, Loss of Instrument Air, as the correct procedure.
COMMENT: Sequence NOT required for this JPM.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Perform Immediate Actions.STANDARD:
Check PI 810 air pressure and for secondary upset.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Verify the standby station air compressor and emergency instrument air compressor have started.STANDARD:
Verify all air compressors are running/Red lights LIT.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Start temp. diesel air compressor.
STANDARD:
Direct EO to start compressor.
CUE: Temp. diesel air compressor is NOT available.
SAT UNSAT 5. PERFORMANCE STEP: Inform all personnel per procedure.
STANDARD:
Announce over the Gai-Tronics.
CUE: None.SAT UNSAT JPM No. 44B Page 10 of 12 JPM No. 44B Page 10 of 12 6. PERFORMANCE STEP: Dispatch an Equipment Operator to verify SA 6445, and SA 236 SA/IA cross-tie valve, are closed.STANDARD:
Verbal communication to verify SA 6445 CLOSED by checking position of NV 6445 OR close SA 234. Verify SA 236 is CLOSED.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Dispatch operators to locate major air leaks.STANDARD:
Operators dispatch to locate major air leaks in the plant.COMMENT: This step may not be performed if DB-OP-02528, Step 4.1.7, is strictly adhered to. This step is not mandatory for satisfactory test completion.
CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Dispatch an operator to close SA 18 and SA 20.STANDARD:
Verbal communication with Equipment Operator to CLOSE SA 18 and SA 20.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Manually TRIP the reactor when IA pressure drops to.C........
75 psig.STANDARD:
Push either REACTOR TRIP button on control board.CUE: None.SAT UNSAT 10. PERFORMANCE STEP: Initiate AFW flow and isolate both SGs..C.STANDARD:
Depress SFRCS MANUAL ACTUATION and ISOLATION switches, HIS 6403 and 6404.CUE: None.SAT UNSAT JPM No. 44B Page 11 of 12 11. PERFORMANCE STEP: Go to DB-OP-02000, RPS, SFAS, SFRCS or SG Tube Rupture Procedure.
STANDARD:
Refer to procedure for reactor trip or SFRCS trip.CUE: DB-OP-02000 is in progress.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 44 Page 12 of 12 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 60 Rev. 05 Page 1 of 5 TASK NO.: 001-044-04-0100 TASK DESCRIPTION:
Clearing an Asymmetry Fault K/A
 
==REFERENCE:==
 
000-003, EK3.04 (3.8/4.1), EA1.03 (3.6/3.3)
GEN.05 (3.6/3.6), GEN.06 (3.5/3.4)APPLICABLE METHOD OF TESTING: Simulate performance In-Plant TIME FOR COMPLETION:
26.5 minutes APPLICABILITY:
[XI RO [X] SRO TASK STANDARDS:
Successfully clear the following alarms: 1. Annunciator alarm "CRD ASYMMETRIC ROD" is off.2. ASYMMETRY FAULT light on the rod control panel is off.REOUIRED MATERIALS:
: 1. CRD Cabinet Key (#11)2. DB-OP-02516, CRD Malfunctions Abnormal Procedure, Revision 03 GENERAL
 
==REFERENCES:==
 
DB-OP-02516, CRD Malfunctions Abnormal Procedure, Revision 03 INITIAL CONDITIONS:
The plant is operating at 78% power. Control Rod 5-3 has been dropped. It is expected to take six hours to realign the control rod. Power is being reduced to 60%.INITIATING CUES: The Shift Supervisor directs you to perform Section 1.0 of Attachment 2 of DB-OP-02516 to clear the ASYMMETRY FAULT light on the rod control panel.(Hand copy of DB-OP-02516, CRD Malfunctions, to the examinee.)
JPM No. 60 Page 2 of 5 INITIAL CONDITIONS:
The plant is operating at 78% power. Control Rod 5-3 has been dropped. It is expected to take six hours to realign the control rod. Power is being reduced to 60%.INITIATING CUES: The Shift Supervisor directs you to perform Section 1.0 of Attachment 2 of DB-OP-02516 to clear the ASYMMETRY FAULT light on the rod control panel.
JPM No. 60 Page 3 of 5 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: l1. PERFORMANCE STEP: Locate the correct Control Rod Drive Cabinet..C.STANDARD:
Locate Control Rod Drive Cabinet C4801T in Electrical Penetration Room 1.CUE: None.SAT UNSAT 2. PERFORMANCE STEP: Place the S2 asymmetry bypass switches in bypass..C.STANDARD:
Place all affected switches on the following API amps in Group 5 in the down position:
C 9, E 11, G 13, K 13, M 11, 0 09, 0 07, M 5, K 3, G 3, E 5, C 7.COMMENT: Provide CUE for appropriate S2 switch as each is placed in BYPASS by the trainee.CUE: S2 switch for Rod (_) has been placed in the DOWN (bypass)position.SAT UNSAT 3. PERFORMANCE STEP: Check the asymmetry bypass light on the rod control panel is ON.STANDARD:
Visual check at the rod control panel.CUE: The ASYMMETRY BYPASS light ON.SAT UNSAT 4. PERFORMANCE STEP: Reset the fault condition..C.STANDARD:
Depress the FAULT RESET button.CUE: FAULT RESET button has been depressed.
SAT UNSAT JPM No. 60 Page 4 of 5 5. PERFORMANCE STEP: Check the CRD asymmetric rod annunciator alarm is extinguished.
STANDARD:
Visual check that annunciator 5-2-E is off.CUE: CRD ASYMMETRIC ROD annunciator (5-2-E) is NOT LIT.SAT UNSAT 6. PERFORMANCE STEP: Check the ASYM ALARM LEDs on the PI panel for Group 5 rods are on.STANDARD:
Visual check of PI panel the Group 5 rods ASYM ALARM LEDs are ON.CUE: All Group 5 ASYM ALARM LEDs are ON.SAT UNSAT 7. PERFORMANCE STEP: Check the asymmetry fault light on the rod control panel is OFF.STANDARD:
Visual check of rod control panel that the ASYMMETRY FAULT light is OFF.CUE: The ASYMMETRY FAULT light is OFF.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 60 Page 5 of 5 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ I SATISFACTORY
[ I UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date JPM No. 85C Page 10 of 16 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Purge Containment in Mode 5.INITIAL CONDITION:
Any mode.ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
-Turn off CTMT Purge Supply and Exhaust Fans.-Close dampers CV 5004, 5016, 5009 and 5021.-Install fuses in SFAS cabinets.-Verify dampers CV 5005, 5006, 5007, and 5008 are closed.MALFUNCTIONS/FAILURE TO INSERT: Prevent start of CTMT Purge Supply Fan by closing air valve to supply damper.-IMF CAV7B ACTION/CUES:
: 1. Step 8, CUE: The only item found out of position was DP6802, circuit 1, which was found open.2. Step 9, ACTION: Remove the malfunction (DMF CAV7B).CUE: DP6802 circuit 1 has been closed.
JPM No. 85C Page 11 of 16 DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 85C Rev. 05 Page 11 of 16 TASK NO.: 029-010-01-0100 TASK DESCRIPTION:
Purge Containment in Mode 5 K/A
 
==REFERENCE:==
 
000-060-EA1.02 (2.9/3.1);
000-060-EA2.06 (3.6/3.8);
029-000-K1.03 (3.6/3.8);
029-000-GEN.09 (2.9/3.1)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
APPLICABILITY:
[X] RO 18 minutes[X] SRO TASK STANDARDS:
Initiate containment vessel purge.REQUIRED MATERIALS:
DB-OP-06503, Containment Purge System Procedure, Revision 00, C-7 GENERAL
 
==REFERENCES:==
 
DB-OP-06503, Containment Purge System Procedure, Revision 00, C-7 INITIAL CONDITIONS:
The plant is in Mode 5. The Containment Purge System had been running on containment.
At the beginning of last shift, containment purge was stopped and purge was started on the Mechanical Penetration Rooms. At the end of last shift, the purge was stopped.INITIATING CUES: The Shift Supervisor directs you to start a containment vessel purge per DB-OP-06503, Containment Purge System Procedure.(Hand copy of DB-OP-06503 to examinee.)
JPM No. 85C Page 12 of 16 INITIAL CONDITIONS:
The plant is in Mode 5. The Containment Purge System had been running on containment.
At the beginning of last shift, containment purge was stopped and purge was started on the Mechanical Penetration Rooms. At the end of last shift, the purge was stopped.INITIATING CUES: The Shift Supervisor directs you to start a containment vessel purge per DB-OP-06503, Containment Purge System Procedure.
JPM No. 85C Page 13 of 16 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure.
STANDARD:
Identifies Section 3.1 of DB-OP-06503, Containment Purge System Procedure, as the correct section.COMMENT: When correct section has been located, provide CUE to trainee.CUE: All prerequisites have been completed.
SAT UNSAT 2. PERFORMANCE STEP: Make a plant announcement.
STANDARD:
Use the GAITRONICS to make the proper announcement.
CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Open the purge CTMT isolation valves..C.STANDARD:
Press the OPEN pushbutton on HIS 5005, 5006, 5007, and 5008.COMMENT: Sequence NOT required.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Start the CTMT purge exhaust fan.STANDARD:
Turn handswitch HIS 5013 to START.CUE: None.SAT UNSAT JPM No. 85C Page 14 of 16 5. PERFORMANCE STEP: Verify automatic actions occur.STANDARD:
Verifies red indicating light for CTMT purge exhaust fan ON.COMMENT: The fan will start in approximately 120 seconds.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Start the CTMT purge supply fan.STANDARD:
Within 20 seconds after the exhaust fan starts, turn handswitch HIS 5003 to START.COMMENT: Fan is failed.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: GO TO Section 4.3.STANDARD:
Verify the CTMT Purge Exhaust Fan is off as well as the CTMT Purge Supply fan.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Send an EO to investigate the problem with the fan.C........
per Attachment 4.STANDARD:
Verbal communication with an Equipment Operator to investigate the problem.CUE: (If asked) The Shift Supervisor directs you to use an EO to check the problem.SAT UNSAT 9. PERFORMANCE STEP: Direct the EO to open the supply damper air valve..C.STANDARD:
Verbal communication with Equipment Operator to open the supply damper air valve.CUE: (If asked) The Shift Supervisor directs you to direct the EO to close breaker DP6802, circuit 1, and he will document the breaker being out of position.SAT UNSAT JPM No. 85C Page 15 of 16 10. PERFORMANCE STEP: Start CTMT purge exhaust fan..C.STANDARD:
Turn handswitch HIS 5013 to START.COMMENT: The fan will start in approximately 120 seconds.CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Verify automatic actions occur.STANDARD:
Verifies red indicating light for CTMT purge exhaust fan is ON.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Start the CTMT purge supply fan..C.STANDARD:
Within 20 seconds after the exhaust fan is running, turn handswitch HIS 5003 to START.COMMENT: Fan is NOT failed.CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Verify automatic actions occur..C.STANDARD:
Visually verify supply fan red light ON.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 85C Page 16 of 16 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date JPM No. 91C Page 19 of 26 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Start High Pressure Injection Pump upon a Loss of One Decay Heat Pump INITIAL CONDITION:
RCS Drained to 80 inches, DH Loop 2 in Service ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
SPDS Decay Heat Removal Screen is not working.Hang Red Tags on HPI Pumps 1 & 2 control switches.MALFUNCTIONS/FAILURE TO INSERT: Insert malfunction to fail Decay Heat Pump 2's breaker open (IMF BDP2C).Insert malfunction to fail Decay Heat Pump l's breaker open (IMF BDP1C).ACTION/CUES:
NOTE: Use proper three-part communication for any necessary cues.1. Step 1: 2. Step 1: 3. Step 12: 4. Step 13: (if sent) Breaker AD112 indicates 50/51 phases A and C relays tripped.(if sent) DH Pump 2 shows no abnormal indications.
Breaker BE 1157-A on EllA for DH7B has been closed. (IRF BD7B)All tags have been removed from breaker AClll. Breaker ACill has been racked in (IRF BFP1A OPERATE).
Breaker AC111 close power fuses have been installed (IRF BFP1C FALSE).
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO. 91C Rev. 00 Page 20 of 26 TASK NO. 005-012-04-0100 TASK DESCRIPTION:
Start High Pressure Injection Pump upon a Loss of One Decay Heat Pump K/A
 
==REFERENCE:==
 
GEN-XXX-2.4.4 (4.0/4.3), 025-XXX-AK3.01 (3.1/3.4)APPLICABLE METHOD OF TESTING: Simulate performance Simulator Alternate procedure TIME FOR COMPLETION:
20 minutes APPLICABILITY:
[X] RO [X] SRO TASK STANDARDS:
Start High Pressure Injection Pump 1 or 2 and establish flow to the RCS.REOUIRED MATERIALS:
DB-OP-02527, Loss of Decay Heat Removal, Revision 02 GENERAL
 
==REFERENCES:==
 
DB-OP-02527, Loss of Decay Heat Removal, Revision 02 INITIAL CONDITIONS:
The plant has been in Mode 5 for 25 days.RCS temperature is 130 0 F.RCS level is 80 inches on LI 10577A and B, RCS level indication, for maintenance activities.
Decay Heat Train 2 is in service.Decay Heat Train 1 is in standby.No RCS boron dilution is in progress.CTMT has been evacuated, CTMT closure has been established.
The SPDS Decay Heat Removal Screen is not functioning.
INITIATING CUES: Decay Heat Pump 2 has tripped on overcurrent.
The Shift Supervisor directs you to start Decay Heat Pump 1 in the decay heat mode using DB-OP-02527.
You have permission to operate any locked valves required.Desired decay heat flow is 1500 gpm.(Hand a copy of DB-OP-02527 to the examinee.)
JPM No. 91C Page 21 of 26 INITIAL CONDITIONS:
The plant has been in Mode 5 for 25 days.RCS temperature is 130 0 F.RCS level is 80 inches on LI 10577A and B, RCS level indication, for maintenance activities.
Decay Heat Train 2 is in service.Decay Heat Train 1 is in standby.No RCS boron dilution is in progress.CTMT has been evacuated, CTMT closure has been established.
The SPDS Decay Heat Removal Screen is not functioning.
INITIATING CUES: Decay Heat Pump 2 has tripped on overcurrent.
The Shift Supervisor directs you to start Decay Heat Pump 1 in the decay heat mode using DB-OP-02527.
You have permission to operate any locked valves required.Desired decay heat flow is 1500 gpm.
JPM No. 91C Page 22 of 26 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: 1. PERFORMANCE STEP: Locate the correct procedure attachment.
STANDARD:
Identify Attachment 3, as the correct procedure attachment.
COMMENT: Examinee will most likely route through Section 4.1 of the procedure to Step 4.1.14, which sends him to Attachment 3.Repeat initiating cues as necessary.
Use proper three-part communication for cues.CUE: (If asked) No signs of pump cavitation existed before the pump tripped.SAT UNSAT 2. PERFORMANCE STEP: Close DH 14B.STANDARD:
Depress auto on HIS DH 14B and verify zero demand is indicated on HIC DH14B and/or Green light comes ON.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Close DH 13B.STANDARD:
Depress auto on HIS DH 13B and verify zero demand is indicated on HIC DH1B and/or Green light is ON.CUE: None.SAT UNSAT 4. PERFORMANCE STEP: Verify DH 1517 is open.STANDARD:
Visual verification of Red light is LIT on HIS 1517.CUE: None.SAT UNSAT JPM No. 91C Page 23 of 26 5. PERFORMANCE STEP: Verify open DH 11 and DH 12 or DH 21 and DH 23.STANDARD:
Visual verification of Red light on HIS DHll and HIS DH12.COMMENT: Use proper three-part communication for cues.CUE: DH 21 and DH 23 are not to be used per SS discretion.
SAT UNSAT 6. PERFORMANCE STEP: Verify CCW and SW cooling is available.
STANDARD:
Verify CCW Pump 1 and SW Pump 1 are running and CC 1467 Red indicating light is LIT.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Verify DH 1B is open.STANDARD:
Visual verification of Red light is LIT on HIS DH1B.COMMENT: Only critical if DH 1B is closed.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Start DH Pump 1 using HIS DH 6B..C.STANDARD:
Recognize DH Pump 1 does not start.COMMENT: Use proper three-part communication for cues.CUE: (If asked) The Shift Supervisor directs you to continue in the Loss of Decay Heat Removal procedure while he investigates the failure of DH Pump 1.SAT UNSAT 9. PERFORMANCE STEP: Determine if either OTSG is functional.
STANDARD:
Determine if RCS is intact.CUE: (If asked) OTSGs are not available.
SAT UNSAT JPM No. 91C Page 24 of 26 10. PERFORMANCE STEP: Establish a feed flowpath.C..STANDARD:
Determine that an HPI Pump is the available feed flowpath.COMMENT: Use proper three-part communication for cues.CUE: (If asked) The Shift Supervisor directs you to establish a feed flowpath using HPI Pump 1.SAT UNSAT 11. PERFORMANCE STEP: Locate the correct procedure attachment.
STANDARD:
Identify Attachment 5, as the correct procedure attachment.
COMMENT: Use proper three-part communication for cuel.CUE: (If asked) The Shift Supervisor has verified the System Status File and Safety Tagging file for HPI show the system valve lineup is complete for Mode 3 entry.SAT UNSAT 12. PERFORMANCE STEP: Establish a flowpath from the BWST through the HPI Pump into the RCS.STANDARD:
Refer to Attachment 10 for flowpaths available.
COMMENT: Examinee may refer to OS 003 and OS 004 or Attachment 10.Examinee may also direct an Equipment Operator to verify the position of DH and HPI valves in the flowpath.
Use proper three-part communication for any necessary cues.CUE: None.SAT UNSAT 13. PERFORMANCE STEP: Restore HPI Pump 1 breaker to service, if necessary.
.C.STANDARD:
Communicate with an EO to remove tags, rack in, and insert close power fuses on 4160 VAC breaker AC111.CUE: (If asked) The Shift Supervisor has given permission to remove the Safety tag from AC111 breaker for HPI pump 1.SAT UNSAT JPM No. 91C Page 25 of 26 14. PERFORMANCE STEP: Close High Pressure Injection valves HP 2A, 2B, 2C, and 2D.STANDARD:
Visual verification of Green light is LIT on HIS HP2C and HIS HP2D.CUE: None.SAT UNSAT 15. PERFORMANCE STEP: Start HPI Pump 1.C.C STANDARD:
Place HIS 1524 to START, then release. Observe the Red light goes ON and the Green light goes OFF.CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Throttle HP 2A, 2B, 2C, and 2D to establish injection.C........
flow.STANDARD:
Press the open pushbutton on HP 2C and HP 2D using HIS HP2C and HIS HP2D until flow is established.
COMMENT: Actual flow rate is not critical at this step, provided some flow is provided.CUE: None.SAT UNSAT 17. PERFORMANCE STEP: Monitor incore thermocouples.
STANDARD:
Examine incore thermocouple temperatures on the PAM Panels.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 91 Page 26 of 26 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date JPM No. 93B Page 8 of 16 SIMULATOR INSTRUCTIONS TASK DESCRIPTION:
Return Decay Heat Train 2 to LPI Mode INITIAL CONDITION:
Mode 4, 270 0 F, 250 psig, Maneuver here from 273 0 F Training IC #36. Only do switch check for front panels. Skip keys to save time!ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
Place Decay Heat Loop 2 in decay heat lineup (DH 1518 OPEN, DH 2734 CLOSED, DH 14A, 13A at 20% demand, CC 1469 OPEN).MALFUNCTIONS/FAILURE TO INSERT: None.ACTION/CUES:
: 1. ACTION: CLOSE DH 60, DH Pump 1-2 Discharge Sample Isolation Valve.CUE: DH 60 is CLOSED.2. ACTION: Verify DH 26, DH Pump 1-2 Minimum Cooldown Isolation Valve.CUE: DH 26 is CLOSED.3. ACTION: Remove the CLOSE power fuses from AD112 for DH Pump 1-2.CUE: The CLOSE power fuses have been removed from AD112, DH Pump 1-2 breaker.4. ACTION: Close BF 1129 and BF 1134 on F1lC and BF 1195 (F1lE).CUE: BF 1129, BF 1134, and BF 1195 have been closed. (Give cue for each breaker as called for.)5. CUE: Attachment 25 has been completed.
: 6. ACTION: Install the CLOSE power fuses in AD112 for DH Pump 1-2.CUE: The CLOSE power fuses have been installed in AD112, DH Pump 1-2 breaker.7. ACTION: Verify DH 14A OPEN locally.CUE: DH 14A is OPEN to the hard stop.
DAVIS-BESSE NUCLEAR POWER STATION JOB PERFORMANCE MEASURE WORKSHEET JPM NO.: 93B Rev. 04 Page 9 of 16 TASK NO.: 005-009-01-0100 TASK DESCRIPTION:
Return Decay Heat Train 2 to LPI Mode K/A
 
==REFERENCE:==
 
005-000-A4.01 (3.6/3.4);
005-000-A4.02 (3.4/3.1)APPLICABLE METHOD OF TESTING: Simulate performance Simulator TIME FOR COMPLETION:
21 minutes APPLICABILITY:
[X] RO[X] SRO TASK STANDARDS:
Lineup Decay Heat Loop 2 to the LPI mode.REOUIRED MATERIALS:
DB-OP-06012, Decay Heat and Procedure, Revision 04 Low Pressure Injection System Operating GENERAL
 
==REFERENCES:==
 
DB-OP-06012, Decay Heat and Low Pressure Injection System Operating Procedure, Revision 04 INITIAL CONDITIONS:
The plant is in Mode 4 with a plant heatup in progress.RCS temperature is 270 0 F.RCS pressure is 250 psig.RCPs 2-1 and 2-2 are running.Decay Heat Loop 1 is aligned for LPI mode.Decay Heat Pump 1-2 has just been stopped.INITIATING CUES: The Shift Supervisor directs you to line up Train 2 of Decay Heat to the LPI mode using DB-OP-06012, Decay Heat and Low Pressure Injection System Operating Procedure.
You have permission to operate all locked valves required for this procedure and the Locked Valve Log entries have been made.(Hand DB-OP-06012 to examinee.)
JPM No. 93B Page 10 of 16 INITIAL CONDITIONS:
The plant is in Mode 4 with a plant heatup in progress.RCS temperature is 270 0 F.RCS pressure is 250 psig.RCPs 2-1 and 2-2 are running.Decay Heat Loop 1 is aligned for LPI mode.Decay Heat Pump 1-2 has just been stopped.INITIATING CUES: The Shift Supervisor directs you to line up Train 2 of Decay Heat to the LPI mode using DB-OP-06012, Decay Heat and Low Pressure Injection System Operating Procedure.
You have permission to operate all locked valves required for this procedure and the Locked Valve Log entries have been made.
JPM No. 93B Page 11 of 16 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is assumed unless denoted in the "Comments".
START TIME: _1. PERFORMANCE STEP: Locate the correct procedure section.STANDARD:
Locates Section 3.13 as the correct section.CUE: All prerequisites are complete.SAT UNSAT 2. PERFORMANCE STEP: Verify DH Pump 2 is stopped using HIS DH 6A.STANDARD:
Verify Green light is lit on HIS DH 6A.CUE: None.SAT UNSAT 3. PERFORMANCE STEP: Verify DH Loop is not aligned to MU and Purfication or SFP Purification.
STANDARD:
Verify Section 4.13 and 4.15 are complete.CUE: Sections 4.13 and 4.15 of DB-OP-06012 were completed on the previous shift.SAT UNSAT 4. PERFORMANCE STEP: Close CC 1469, DH Cooler 1-2 CC outlet.STANDARD:
Depress CLOSE pushbutton on HIS 1469.COMMENT: Trainee may also elect to STOP CCW Pump 2 due to low flow caused by CLOSING CC 1469.CUE: None.SAT UNSAT JPM No. 93B Page 12 of 16 5. PERFORMANCE STEP: Verify DH 830/DH 831, DH Cooler 1-1/1-2 cross connects are closed.STANDARD:
Verify Green light LIT on HIS 830/DH 831.CUE: None.SAT UNSAT 6. PERFORMANCE STEP: Verify closed DH 2735 & DH 2736 DH aux. spray valves.STANDARD:
Verify Green light LIT on HIS 2735 and HIS 2736.CUE: None.SAT UNSAT 7. PERFORMANCE STEP: Verify DH lA, DH Pump 1-2 discharge to RCS is open with control power removed.STANDARD:
Verify Red light on HIS DH1A is LIT and Blue "CTRL PWR OFF" light is Lit on HIS DHIA-2.CUE: None.SAT UNSAT 8. PERFORMANCE STEP: Verify DH 7A, BWST Line 2 isolation is open.STANDARD:
Verify Red light LIT on HIS DH7A.CUE: None.SAT UNSAT 9. PERFORMANCE STEP: Remove close power fuses for AD112.STANDARD:
Dispatch an Equipment Operator to remove the "CLOSE" power fuses from AD112 for DH Pump 1-2.CUE: None.SAT UNSAT JPM No. 93B Page 13 of 16 10. PERFORMANCE STEP: Close Breaker BF1129 (FliC)..C.STANDARD:
Dispatch an EO to close Breakers BF 1129 (DH 1518).CUE: None.SAT UNSAT 11. PERFORMANCE STEP: Close DH 1518, DH Pump 1-2 suction from RCS..C.STANDARD:
Depress CLOSE HIS 1518.CUE: None.SAT UNSAT 12. PERFORMANCE STEP: Close Breaker BF1195 (FllE).STANDARD:
Dispatch an EO to close BF1195 (FilE).CUE: None.SAT UNSAT 13.PERFORMANCE STEP: Verify DH 63, DHR CLR 2 outlet to HPI Pump 2 suction, is CLOSED.STANDARD:
Verify Green light is lit on DH 63.CUE: None.SAT UNSAT 14. PERFORMANCE STEP: Bleed off pressure from suction line of DH Pump 1-2.STANDARD:
Dispatch EO to bleed OFF pressure from DH Pump 1-2 suction line, per Step 3.13.21.CUE: None.SAT UNSAT JPM No. 93B Page 14 of 16 15. PERFORMANCE STEP: Close Breaker BF1134 (FliC)..C.STANDARD:
Dispatch an EO to close Breaker BF1134 (FliC)CUE: None.SAT UNSAT 16. PERFORMANCE STEP: Open DH 2734, DH Pump 1-2 suction from BWST or emerg..C........
sump.STANDARD:
Depress OPEN on HIS 2734.CUE: None.SAT UNSAT 17. PERFORMANCE STEP: Install close power fuses in AD112..C.STANDARD:
Dispatch an Equipment Operator to install the "CLOSE" power fuses in AD112 for DH Pump 1-2.COMMENT: Only critical if the fuses were removed previously.
CUE: None.SAT UNSAT 18. PERFORMANCE STEP: Notify the Shift Supervisor that DH Loop 2 is in standby LPI mode and to perform an operability evaluation.
STANDARD:
Communicate with the Shift Supervisor to inform him of the DH/LPI System status and request operability evaluation.
CUE: The Shift Supervisor acknowledges DH Loop 2 in LPI mode. LPI Loop 2 has been determined to be operable.SAT UNSAT JPM No. 93B Page 15 of 16 19. PERFORMANCE STEP: OPEN DH 14A, DH Cooler 1-2 outlet flow controller..C.STANDARD:
Set HIC DH14A to about 67% OPEN, depress OPEN on HIS DH14A.CUE: None.SAT UNSAT 20. PERFORMANCE STEP: Close DH 13A, DH Cooler 1-2 bypass flow controller..C.STANDARD:
Set HIC DH13A to zero demand, depress CLOSE on HIS DH13A.CUE: None.SAT UNSAT 21. PERFORMANCE STEP: Within 4 hours, locally verify DH 14A, indicates 2834% -3114% open.STANDARD:
Dispatch an Equipment Operator to verify DH 14A OPEN locally.CUE: The Unit Log entry, for DH 14A position, has been made.SAT UNSAT 22. PERFORMANCE STEP: Verify DH 60, DH Pump 2 Discharge Sample Isolation, is open.STANDARD:
Dispatch an equipment operator to verify DH 60 open.CUE: None.SAT UNSAT TERMINATING CUES: This JPM is complete.END TIME JPM No. 93B Page 16 of 16 VERIFICATION OF COMPLETION Operator Evaluator SSN Date License: [ ] RO [ ] SRO Validated Completion Time: minutes Actual Completion Time: minutes Acceptable Progress Maintained:
Yes No N/A Result: [ ] SATISFACTORY
[ ] UNSATISFACTORY NOTE: An "Unsatisfactory" requires Comment and will require subsequent remedial training.Comments/Feedback:
Evaluator's Signature Date INITIAL SUBMITTAL OF THE SCENARIOS FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13, 1999 Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 1 Op-Test No.: 1 Examiners:
Operators:
Objectives:
The RO candidates are to (1) perform the operator actions during a Plant startup beginning at 5% power and increase power to 10% or greater, (2) implement the actions for a power range NI failing high, (3) determine the need to trip the Main Turbine due to a Main Stop Valve failing open during Main Turbine Shell warming, (4) start Makeup Pump 2 due to an oil leak on Makeup Pump 1, (5) stop the Steam Generator 1 overfill due to Steam Generator 1 Startup Level instrument failing high, (6) trip the reactor due to a steam leak on AFPT 2, (7) establish MU/HPI cooling and (8) feed Steam Generator 2 with the Startup Feedwater Pump due to a loss of all feedwater.
Turnover:
Plant was shutdown for bushing replacement on the Main Transformer, Reactor startup is in progress and currently at -5%. Completed testing of both AFPTs for operability.
Planned: Continue Reactor startup and begin Main Turbine shell warming. In Progress:
Line-ups for placing MDFP in AFW mode, I&C changing RE600 & RE609 set point. Equipment OOS: Stator Coolant Pump B for motor replacement.
Event Malf. No. Event Event No. Type* Description 1 R(RO) Continue reactor startup from about 5% to about 14%.2 N(BOP) Establish main turbine shell warming.3 IMF UV02C C(BOP) Fail open Main Turbine Stop Valve 2 after main turbine shell TRUE warming has been started.4 IMF R3N5 100 I(RO) Fail Power Range Nuclear Instrument, NI-5, high.IMF R3N1 100 5 IMF BME5J C(RO) Oil leak on Makeup Pump 1 after the rod control panel is placed 0.5 in automatic.
6 IMF L1TL28 l(BOP) Slow failure of Steam Generator 1 Startup Level Transmitter, 0.0 LT SP9B4, to zero.7 IMF FKPBC M(AII) After Steam Generator 1 level control has been established or TRUE C(AII) the reactor trips, a steam leak on AFPT 2 develops with MS IMF SFEG 1.0 107A failed in the open position.IMF SFECD Loss of all feedwater due to a steam leak on AFPT 2 and AFPT 1.0 1 Governor controlling at 500 rpm.500 Motor drive feed pump breaker will not close.* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 1 & 2 Page 1 of 1 Event
 
== Description:==
 
Continue Reactor startup from about 5% to about 14%.Establish main turbine shell warming.Time l Position l Applicant's Actions or Behavior SRO Direct a plant startup per DB-OP-06901, starting at Step 3.37-Increase reactor power to 14%.-NIP and HBP check every 5% power change.-Main turbine shell warming.-Place Main Feedwater Pump 1 in standby.RO Increase reactor power to 14% at 350F/hr.-Perform a NIP and HBP check every 5% power change BOP Initiate main turbine shell warming per DB-OP-06202, Turbine Operating Procedure, Section 3.3:-Pressurize the main turbine shell to 60 psig.BOP Place Main Feedwater Pump 1 in standby per DB-OP-06224, Main Feed Pump and l _ Turbine, Section 3.5.I. I 4 4+ 4+ 4 1- 4+ 4+ 4 2 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 3 Page 1 of 1 Event
 
== Description:==
 
Fail open Main Turbine Stop Valve 2 after main turbine shell warming has been started.Time Position Applicant's Actions or Behavior BOP Identify that Main Stop Valve 2 has failed open:-Annunciator Alarms 14-3-F, HPT MN STM PRESS.SRO Direct the implementation of DB-OP-02525, Steam Leaks.-Determine that tripping of the main turbine is required.BOP Determine that tripping of the main turbine is required and trip the main turbine.SRO/BOP Direct the implementation of DB-OP-02500, Turbine Trip.-Verify immediate actions.-Check MFW on low level limits.-Steam generator pressures are at 870 psig.4 4+4.1 4 1- 4 4 4 4 +1 4-1 +I I 3 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 4 Page 1 of 1 Event
 
== Description:==
 
Fail Power Range Nuclear Instrument, NI-5, high.Time Position [ Applicant's Actions or Behavior RO Identify that Power Range NI-5 has failed high.-Annunciator 5-1-H, RPS CH 2 TRIP.-Annunciator 5-2-H, RPS HI FLUX TRIP.-Power is failed high on NI N15, NI-5 Power Range indicator.
SRO Direct the implementation of DB-OP-02505, Nuclear Instrumentation Failures.-Verify immediate action.-RO to place rod control panel in manual.RO Place rod control panel in manual.Reactor power is stabilized and held constant or restored to previous level.SRO Direct placing RPS Channel 2 in bypass and NI-5 power range test module in 'Test Operate' using DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure.
BOP Place RPS channel 2 in Bypass and NI-5 Power Range Test module in 'Test Operate using DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating procedure.
SRO Direct the restoration of ICS to full automatic using DB-OP-06401, Integrated Control System Operating Procedure.
RO Return lCS to full automatic.
-Place the Rod Control Panel in Auto.4 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: I Scenario No.: 1 Event No.: 5 Page 1 of 1 Event
 
== Description:==
 
Oil leak on Makeup Pump I after the Rod Control Panel is place in automatic.
Time Position J Applicant's Actions or Behavior RO Identify that Makeup Pump 1 has an oil leak or that Makeup Pump 1 has tripped on low oil pressure.-Annunciator Alarm 2-1-A, MU PMP 1 LUBE OIL PRESS LO.-Annunciator Alarm 6-5-C, SEAL INJ FLOW LO.-Annunciator Alarm 6-6-C, SEAL INJ TOTAL FLOW.-Makeup Pump 1 breaker indicates open, AC 105.RO Verify immediate actions of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify CCW to the RCPs.SRO Direct the implementation of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify immediate actions. -l-Route to DB-OP-02512, Loss of RCS Makeup.SRO Direct the implementation of DB-OP-02512, Loss of RCS Makeup and DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify immediate actions.-RO to close RCP Seal Injection Flow Control Valve, MU19 and Pressurizer Level Control Valve, MU 32.-RO to start the Makeup Pump 2.-RO to re-establish seal injection flow using MU19.-RO to return Pressurizer Level Control Valve, MU 32, to automatic.
RO Close RCP Seal Injection Flow Control Valve, MU1 9 and Pressurizer Level Control Valve, MU 32.Critical Task: 022-AA1.09 3.2/3.3 RO Start Makeup Pump 2 per DB-OP-06006, Makeup and Purification System, Section 3.3.RO Return Pressurizer Level Control Valve, MU 32, to automatic.
RO Re-establish seal injection flow using MU19.4 +I 4 I 4 I 5 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Page 1 of 1 Event
 
== Description:==
 
Slow failure of Steam Generator 1 startup level instrument, LT SP9B4, to zero.Time Position Applicant's Actions or Behavior BOP Determine that Steam Generator 1 has an overfill in progress.-Annunciator 14-5-E, ICS SG 1 ON LO LVL LIMIT.-Annunciator 14-4-E, ICS INPUT MISMATCH.-Raising level on Li SP9B8A, Steam Generator 1 Startup Level Indicator.
SRO Direct the implementation of DB-OP-02526, Steam Generator Overfill.-BOP to place Main Feedwater Loop 1 control valves in hand.-BOP to restore Steam Generator 1's level to 40".BOP Place Main Feedwater Control Valve FW SP7B and FW SP6B, if FW 780 is open, into hand, and maintain 40" in Steam Generator 1.SRO Direct Steam Generator 1 startup level be transferred to the Y' instrument per DB-OP-06407, Non-Nuclear Instrumentation Operating Procedure, Section 4.1.BOP Select the 'Y' Steam Generator 1 startup level instrument per DB-OP-06407, Non-Nuclear Instrumentation Operating Procedure, Section 4.1.4 .4 4 .4.1.+ 4+ 4.1.+ '4 I1 4 +4. +4. +.4 4 6 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Page 1 of 3 Event
 
== Description:==
 
After Steam Generator 1 level control has been established or the reactor trips a steam leak on AFPT 2 occurs with MS 107A failed in the open position.Loss of all feedwater due to steam leak on AFPT 2 and AFPT 1 governor controlling at 500 rpm.Time Position Applicants Actions or Behavior All Identify a steam leak on AFPT 2.-Fire alarms.-Annunciator
'SG 1 TO AFPT 2 MN STM PRESS LO', 12-2-A.SRO Direct the implementation of DB-OP-02525, Steam Leaks:-BOP to attempt to isolate the leak.-RO to trip the reactor.-BOP to isolate AFW to Steam Generator 1 and open the atmospheric vent valve on Steam Generator 1.-Go to DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture.BOP Close MS 107A, SG 1 to AFPT 2.Identify that MS 107A failed to close.RO Trip the reactor.BOP Close AF 608, AFW to SG 1, and open Atmospheric Vent Valve 1 Critical Task: 040-AA2.01 4.2/4.7 4 4J 4 4.1- 4 4. +.1. 4 4. -I 7 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Page 2 of 3 Event
 
== Description:==
 
After Steam Generator 1 level control has been established or the reactor trips, a steam leak on AFPT 2 occurs with MS 107A failed open position.Loss of all feedwater occurs due to a steam leak on AFPT 2 and AFPT 1 governor controlling at 500 rpm.Time Position l Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture-Verify immediate actions.-BOP to determine the status of the motor drive feed pump.-Give Attachment 1 to the BOP to start the startup feed pump or motor driven feed pump and continue with the RO.-RO to lock both makeup pump suctions on the BWST.-RO to implement MU/HPI cooling per Attachment 4.-Route to Section 12.RO/BOP Verify immediate actions.BOP Identify a loss of all feedwater.
BOP Determine the status of the motor drive feed pump, which is unavailable due to transfer lineup being in progress and breaker will not close.RO Lock both makeup pump suctions on the BWST.RO Align MU/HPI cooling per Attachment 4.*Critical Task: E04-EK3.3 4.2/3.8-Start standby CCW pump.-*Start both HPI pumps.-*Open HP 2A through D, HPI injection valves.-*Start both LPI pumps.-*Open piggyback valves, DH63 and DH64.-*Trip all but one RCP.-Place all pressurizer heaters in off.-*Close Makeup Pump 1 to Seal Injection Valve, MU6409.-*Open Pressurizer Level Control Valve Bypass, MU6420.-Open Makeup Alternate Injection Line CTMT Isolation, MU6421.-Open Makeup Alternate Injection Valve, MU6419.-Close Makeup Pump 2 Minimum Recirc., MU6406-*Open PORV Block Valve, RC1 1.-*Lock open PORV, RC2A.-Open High Point Vent Valves, RC4608A, RC4608B, RC461 OA, RC461 OB, RC200 and RC239A.-Close CTMT Normal Sump Valves, DR2012A and DR2012B.-*Trip the last running RCP when subcooling margin is lost.8 of 13 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Page 3 of 3 Event
 
== Description:==
 
After Steam Generator 1 level control has been established or the reactor trips a steam leak on AFPT 2 occurs with MS 107A failed in the open position.Loss of all feedwater occurs due to a steam leak on AFPT 2 and AFPT 1 oovernor controlling at 500 rpm.Time Position Applicant's Actions or Behavior BOP Align and start the startup feed pump to feed Steam Generator 2 per Attachment 1.-Have an EO align the startup feedwater pump per DB-OP-06226, Startup Feedwater Pump System Operating Procedure.
-Close the Startup Feedwater Control Valve, SP7A.-Open the Main Feedwater Stop Valve, FW601.-Block and reset the Startup Feedwater Control Valve, SP7A.-Establish
< 300 gpm to Steam Generator 2.Termination Criteria:-MU/HPI cooling established.
-Startup feedwater pump providing flow to one of the steam generator.
-Incore temperature is decreasing.
i -t 4 4 4 4 I I 4 I 4 I 9 of 13 Justification for Critical Tasks A. Close the RCP Seal Injection Flow Control Valve, MU19.Failure to close the RCP Seal Injection Flow Control Valve, MU19, when Makeup Pump 2 is started will result in pressure shocking of the RCP seals. This can lead to multiple RCP seal failures and increased RCS leakage. Closing the RCP Seal Injection Flow Control Valve, MU19, will prevent RCP seal damage when Makeup Pump 2 is restarted.
B. Close AF 608, AFW to SG 1, and open Atmospheric Vent Valve 1 The steam leak on AFPT 2 steam supply line and MS 107A being failed open results in a steam leak on Steam Generator 1 that cannot be isolated.
The SFRCS System will not actuate due to the size of the reducer in the AFPT steam supply line. The operator is required to take actions to actuate SFRCS and blow down Steam Generator 1 to eliminate the potential overcooling source.C. Establish MU/HPI Cooling MU/HPI cooling is required to be established when only one makeup pump is available during a loss of all feedwater.
Establishing MU/HPI cooling will prevent the RCS pressure from exceeding the shut off head of the only makeup pump.10 of 13 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -5% power with reactor startup in progress with MFPT 2 in service.2) Verify that EHC load limiter is set at 10.3) Align valves as required per Step 3.4.4 of DB-OP-06202, Turbine Operating Procedure.
: 4) Place one of the power range NIs on a one minute video trend.5) Hang magnetic tag for stator coolant water pump B OOS.a) Place on status board that SCW Pump B is 00S for motor replacement.
: 6) Hang the chemistry sheet on the status board.7) Assign the MDFP to an EO on shift assignment board.8) Post Protected Train 1.9) Post on the Equipment status board a Tech. Spec. Status sheet for T.S. 3.1.3.6, Group 38 inoperable for Rod Insertion limits.10) Initial malfunctions.
a) Rack out Stator Coolant Pump B -IRF UJSB OPEN b) Pull the Close Power fuses on MDFP -IRF FKPBA BLOWN c) Fail open MDFP Breaker- IMF FKPBC b. Procedures
: 1) For Crew: a) DB-OP-06901, Plant Startup Procedure signed off appropriately to Step 3.37 b) DB-OP-06902, Power Operations Procedure c) DB-OP-06202, Turbine Operating Procedure signed off up to Section 3.3 d) DB-OP-06224, Main Feed Pump and Turbine Procedure with Section 3.3 signed off 11 of 13 e) DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure f) DB-OP-06401, Integrated Control System Operating Procedure g) DB-OP-06006, Makeup and Purification System Procedure h) DB-NE-03220, Imbalance, Tilt & Rod Index Calcs -Group 38 Alarms Inoperable, with Attachment 4 completed and a time of one hour prior from current time.2) For Simulator Instructor:
a) DB-OP-06202, Turbine Operating Procedure b) DB-OP-06224, Main Feed Pump and Turbine Procedure c) DB-OP-06226, Startup Feedwater Pump System Operating Procedure c. Event Triggers 1) Activates Event 8 on a SFRCS Trip -TRGSET 8 "F3JPQ963" d. Events 1) Fail open Main Turbine Stop Valve 2 -IMF UV02C (3)2) Fail NI 5 high -IMF R3N5 (4) 100 and IMF R3N1 (4) 100 3) Oil leak on Makeup Pump 1 -IMF BME5J (5) 0.5 4) SG 1 startup level instrument, LT SP984, ramp to 0 over 5 minutes -IMF L1TL28 (6) 0.0 5:00 0.16 5) Initiate AFPT steam supply line leak -IMF SFEG (7) 1.0 6) Fire alarms for AFP Room 2 -IMF KN098 (7), IMF KN101 (7), IMF KN099 (7) and IMF KN100 (7)7) Fail MS 107A open -IMF SFECD (7) 1.0 8) Fail AFPT 1 governor to 500 rpm -IMF SFEJB (8) 500 2. Cues (non-generic)
: a. Event 1 and 2 1) Report as Reactor Engineering that DB-NE-03233, Incore Instrument Channel Check, has been completed.
12 of 13 2)b. Event 3 1)c. Event 4 1)d. Event 5 1)2)EO to report that low pressure turbine thermocouples are all >120F.I & C and Engineering sent to check out Main Stop Valve 2. Engineering will report, if pressed, that Main Stop Valve 2 is jammed in the open position.None.EO sent to the Makeup Pump Room will report oil on the floor.EO sent to Makeup Pump Breaker AC105 would report that Phase A indicates an overcurrent.
: e. Event 6 1)f. Event 7 1)2)None.EO working on MDFP will report back when MDFP is aligned to the AFW mode.EO sent to MDFP will report that there are no indications of a problem with Breaker AD210.13 of 13 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/?/1999 Date: 9/?/1999 Daily Average Limits Value Limits Value S100 02 <2 ppb <5 02 0.9 ppb<150 Cl 4.42 ppb 220 N 2 H 4  32.9 ppb<150 F- 2.35 ppb <20 SiO 2  <5 ppb Li 2.20 ppm 3 Na <0.1 ppb pH 6.88 ( <10 Fe <10 ppb 25-50 H 2  35.8 cc/kg <5 Cl- 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 ,100 TDG 37.8 cc/kg Measured H+Cond. 0.425 iLS/cm1.0 DEI-131 1.13E-2 giCi/gm 0.2 **Inorganic H+ Cond. 0.06 gtS/cm 100/E Specific Act. 0.461 9Ci/m1 Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 jiCi/nl **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS Tank %H 2  %02 &deg;/&deg;N 2  Time Date WGST CWRT 1 CWRT 2 BORON Primary to Secondary Leakage Vessel PPM Time Date RCS ? 0830 9/?9/1999
<5.0 GPD (LLD is 5.0 GPD)PZR ? 1220 9/?/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST Based on RCS Xe-133 _ pCi/ml BAAT I Based on FI 1002 cfmn BAAT2 RE 1003A RE 1003B CWRT 1 5 GPD cpm cpm CWRT 2 30 GPD cpm cpm CFT 1 100 GPD cpm cpm CFT 2 150GPD cpm cpm SFP Increase of Refuel Canal 60 GPD cpmt cpmt Reviewed by Time/Date/Shift Supervisor TECH SPEC STATUS Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.1.3.6 9/?/1999 Rod Insertion Limits due to Verify Rod Insertion Limits at? Group 38 being inoperable.
least once per 4 hours.July 20, 1999 S:\OPSGENERAL\Turnover Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 2 Op-Test No.: 1 Examiners:
Operators:
-Objectives:
The RO candidates are to (1) perform a power increase beginning at 40% power to -50% or greater, (2) startup MFPT 1, (3) identify a sheared shaft on a condensate pump and start the standby condensate pump, (4) control the amount of steam being release through AVV 2 and TBV 2 due to the Steam Generator 2 outlet pressure instrument failure, (5) determine that a letdown cooler is leakina and isolate it, (6) determine that the reactor demand and feedwater loop demands must be placed in manual due to the T-hot instrument failure and (7) trip all RCPs for the loss of SCM due to the pressurizer code safety failing open.Turnover:
Plant is currently at -40%, plans are to continue raising power to 50% at 5 MWe/minute and startup MFPT 1.Equipment OOS: Makeup Pump 1 for bearing replacement and TPCW PumD 1 for PMs.Event Malf. No. Event Event No. Type* Description 1 R(RO) Raise power from 40% to 50%.2 N(BOP) Startup MFPT 1.3 IMF FAK40 C(BOP) Sheared shaft on Condensate Pump 1 after the startup of MFPT TRUE 1.4 IMF L1T334 I(BOP) Steam Generator 2 Outlet Pressure 'X' Instrument, PT SP12A2, 1.0 failed high.5 IMF BME1 B C(RO) Letdown Cooler 1 leaks into Component Cooling Water System 0.5 that develops over 5 minutes.6 IMF LIT6H 1.0 l(BOP) Slow mid-scale failure of RCS Loop 2 T-hot instrument, TT RC3A1 after letdown has been restored.7 IMF FAAWB M(AII) After the plant has been stabilized with ICS station still in TRUE manual, Loop 1 and 2 Main Feedwater Block Valves, FW779 IMF FAB4B and FW780, fail closed.TRUE 8 IMF HV40C M(AII) Pressurizer code safety fails open on a reactor trip.TRUE 9 IMF FAAZC C(BOP) Main Feedwater Startup Control Valve, FW SP7A, fails open TRUE with SFRCS failing to automatically to actuate.IMF FA300 TRUE* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 1 & 2 Page 1 of 1 Event
 
== Description:==
 
Raise power from 40% to 50%.Startup MFPT 1.Time Position Applicant's Actions or Behavior SRO Direct the Implementation of DB-OP-06902, Power Operations.
-RO to raise power to 50% at 5 MWe/min.-Verify all four channels of ARTS are enabled.-BOP is to startup Main Feedwater Pump 1 per DB-OP-06224, Main Feedwater Pump Operating Procedure, Section 3.6.-BOP to place the MFP 1 ICS Station in automatic per DB-OP-06401, Integrated Control System Operating Procedure.
RO Raise power to 50% at 5 MWe/min.BOP Verify all four channels of ARTS are enabled.BOP Startup Main Feedwater Pump 1 per DB-OP-06224, Main Feedwater Pump Operating Procedure, Section 3.6 starting a Step 3.6.32. ; l-Run MFPT I speed up to the ICS Low Speed Stop of 3900 rpm.-Transfer MFPT I to ICS manual per Section 3.7.-Place all four channels of ARTS in operate for MFP 1.(Inform trainee that Fuse in step 3.6.36 is installed.)
BOP Place MFP 1 ICS Station in automatic per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.7.-r+ 4+ II+ II+ I 2 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 3 Page 1 of 1 Event
 
== Description:==
 
Sheared shaft on Condensate Pump 1 after the startup of MFPT 1.Time [ Position I Applicant's Actions or Behavior BOP Identify that Condensate Pump 1 has sheared its shaft.-Low amps on Condensate Pump 1.-Annunciator 13-2-B, CNDS PMP DISCH HDR PRESS.-Indication that CD 2796, Condensate Pump Discharge Header Pressure Control Valve, is not fully open.SRO Direct the startup of Condensate Pump 3 and shutdown of Condensate Pump 1.-May have the BOP place CD 420 and CD 421, Deaerator Storage Tank Level Control Valves, in hand and establish manual control over the condensate pump discharge header pressure.-BOP to start Condensate Pump 3 and shutdown Condensate Pump 1 per DB-OP-06221, Condensate System, Sections 3.5 and 3.6.BOP If directed, place CD 420 and CD 421, Deaerator Storage Tank Level Control Valves, in hand and establish manual control over the condensate pump discharge header pressure.BOP Start Condensate Pump 3 per DB-OP-06221, Condensate System, Section 3.5.BOP Stop Condensate Pump 1 per DB-OP-06221, Condensate System, Section 3.6.+ I I I I I I 4________ I _____________
I ________________________________________________________________
3 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 4 Page 1 of 1 Event
 
== Description:==
 
Steam Generator 2 Outlet Pressure 'X' Instrument, PT SP12A2, failed high.Time Position Applicant's Actions or Behavior BOP/RO Identify that Steam Generator 2 outlet pressure instrument has failed high.-Annunciator 14-6-F, ICS SG 2 BTU LIMIT.-Annunciator 14-4-E, ICS INPUT MISMATCH.-Rising pressure on PI SP12A, Steam Generator 2 outlet pressure indicator.
SRO Direct the implementation of DB-OP-02014, MSRIICS Alarm Panel 14 Annunciator.
-BOP to place Atmospheric Vent Valve 2 in hand and Loop 2 turbine bypass valves in hand per DB-OP-06401, Integrated Control System Operating Procedure, Sections 3.20 and 3.19.-May have the Loop 2 turbine bypass valves manually isolated locally.-BOP to transfer the ICS input for Steam Generator 2 outlet pressure to the Y'instrument per DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure, Section 4.1.-BOP to place Atmospheric Vent Valve 2 in automatic and Loop 2 turbine bypass valves in automatic per DB-OP-06401, Integrated Control System Operating Procedure, Sections 3.11 and 3.10.BOP Place Atmospheric Vent Valve 2 in hand and Loop 2 turbine bypass valves in hand per DB-OP-06401, Integrated Control System Operating Procedure, Sections 3.20 and 3.19.BOP Transfer the ICS input for Steam Generator 2 outlet pressure to the 'Y instrument per DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure, Section 4.1.Critical Task: 015-K405 4.3/4.5 BOP Place Atmospheric Vent Valve 2 in automatic and Loop 2 turbine bypass valves in automatic per DB-OP-06401, Integrated Control System Operating Procedure, Sections 3.11 and 3.10.1-1~ I 4-4-4 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 5 Page 1 of 1 Event
 
== Description:==
 
Letdown Cooler 1 leak into Component Cooling Water System that develops over 5 minutes.Time Position I Applicant's Actions or Behavior RO Identify Letdown Cooler 1 is leaking into the CCW System.-Annunciator 11-1-A, CCW RETURN RAD HI.-Computer point P101, CC OUT LETDOWN HX PRESS.-RE 1412, CCW Line 1 Monitor, is reading higher or in alarm.SRO Direct the implementation of DB-OP-02523, Component Cooling Water System Malfunctions.
-Verify letdown is isolated.-RO to close MU 32, Pressurizer Level Control Valve.-RO to reduce the seal injection flow to 3 gpm per RCP using MU 19, RCP Seal Injection Flow Control Valve, in hand.-RO to return the unaffected letdown cooler to service using DB-OP-06006, Makeup and Purification System, Section 4.16.-RO to return MU 32 to automatic.
-RO to return seal injection flow to normal using DB-OP-06006, Makeup and Purification System, Section 3.9 or DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation and place MU 19 in automatic.
RO Place MU 32, Pressurizer Level Control Valve, in hand and close the valve.RO Place MU 19, RCP Seal Injection Flow Control Valve, in hand and reduce the seal injection flow to 3 gpm per RCP.RO Return the unaffected Letdown Cooler to service per DB-OP-06006, Makeup and Purification System, Section 4.16.RO Return MU 32 to automatic.
RO Return seal injection flow to normal per DB-OP-06006, Makeup and Purification System, Section 3.9 or DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation and place MU 19 in automatic.
I_ I__ ___ _____5 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 6 Page 1 of 1 Event
 
== Description:==
 
Slow mid-scale failure of RCS Loop 2 T-hot instrument.
TT RC3A1.[ Time] Position Applicant's Actions or Behavior RO Determine RCS Loop 2 T-hot instrument is failing midscale.-Annunciator 14-4-E, ICS INPUT MISMATCH.-Annunciator 14-4-D, ICS FW LIMITED BY RX PWR.-Annunciator 4-2-B, HOT LEG TEMP HI.SRO Direct the RO and BOP to perform the following:
-RO to place the reactor demand station into hand and the rod control panel into manual.-BOP to place the steam generator feedwater demand stations into hand.-Have the operators stabilize and balance the plant.RO Place the reactor demand station into hand and the rod control panel into manual.BOP Place the steam generator feedwater demand stations into hxand.RO/BOP Coordinate efforts to stabilize the plant.RO/BOP Balance the primary heat production to the secondary heat removal.I1 I. I.1. 4 I1 I-I.4 I i 4 i I i I i I4 I 4-4.I i___________
____________________
I ______________________________________________________________________________________________
6 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 7. 8 & 9 Page 1 of 2 Event
 
== Description:==
 
After the plant has been stabilized with ICS stations still in manual, Loop 1 and 2 Main Feedwater Block Valves, FW779 and FW780, fail closed.Pressurizer code safety fails open on a reactor trip.Main Feedwater Startup Control Valve, FW SP7A, is failed open with SFRCS failing to automatically actuate.Time l Position Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture-Verify immediate actions.-BOP to manually initiate and isolate SFRCS.-Have Specific Rule 1 performed when subcooling margin is lost.-RO to isolate letdown, PORV and pressurizer spray.-Route to Section 5, Lack of Subcooling Margin, of DB-OP-02000.
-Verify the RCS high point vents are isolated.-When subcooling margin recovers then route to Section 13, Solid Cooldown or Pressurizer Recovery.ROIBOP Verify immediate actions.BOP Identify that FW SP7A has failed to close.Manually initiate and isolate SFRCS.Critical Task: E02.EK3.3 3.6/3.4 4 I t 4 4_ I __ ___________
+----7 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 78 & 9 Page 2 of 2 Event
 
== Description:==
 
After the plant has been stabilized with ICS stations still in manual, Loop 1 and 2 Main Feedwater Block Valves, FW779 and FW780, fail closed.PrPesiri7Pr code qnfitv faik nnnn nn n re2rntnr frin--- ----I---. ____ -1. -1. -. Main Feedwater Startuo Control Valve. FW SP7A. is failed oMen with SFRCS failing to auitnmptipalvl actuate.Time Position Applicant's Actions or Behavior RO Perform Specific Rule 1 when subcooling margin is lost.-Trip all running RCPs with two minutes.Critical Task: E13-EK3.4 3.5/3.7-Lock makeup pump suction valves on the BWST.-Start standby CCW Pump.-Start both LPI Pumps.-Open piggyback valves, DH63 and DH64.-Open MU 6420, MU 32 bypass valve.-Place the alternate makeup injection line in service.-Start both HPI pumps.-Open HP 2A through D, HPI injection valves.RO Isolate Letdown, PORV and Pressurizer Spray.RO Verify the RCS high point vents are isolated.Termination criteria:-Normal post trip secondary conditions on AFW.-Subcooling margin > 20 0 F.-Makeup and HPI have been throttled to maintain subcooling margin.8 of 12 Justification for Critical Tasks A. Transfer the ICS input for Steam Generator 2 outlet pressure instrument to the 'Y' instrument.
The failed Steam Generator 2 Outlet Pressure 'X' Instrument results in the Atmospheric Vent Valve (AVV) 2 failing open and the Loop 2 Turbine Bypass Valves (TBVs) failing open. Placing the AVV 2 Station into hand will close the AW 2. The Loop 2 TBVs cannot be closed unless locally isolated.
The failed instrument will cause ICS to raise reactor power to recover MWe and affect the response of secondary heat removal on a reactor trip. The response to a reactor trip would be an overcooling event. The operator selecting the Steam Generator 2 Outlet Pressure to the Y' instrument will close the TBVs and allow proper response of secondary heat removal.B. Manually initiate and isolate SFRCS.The Main Feedwater Startup Control Valve 2 being failed open will cause an overfill event. The overfill event in conjunction with the small break LOCA will cause an overcooling of the RCS and Steam Generator
: 2. The operator initiating and isolating the SFRCS will terminate the event.C. Trip all running RCPs with two minutes.The pressurizer code safety failing open will cause a loss of subcooling margin which requires that Specific Rule 1 be implemented.
The RCPs are required to be tripped within two minutes due to an analysis showing that the reactor core may be uncovered if the RCPs were to trip after the two minutes expired. The operator tripping the RCPs within two minutes eliminate the chance of the reactor core being uncovered.
9 of 12 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -40% power with reactor startup in progress with: a) MFPT 2 in service.b) MFPT 1 at -1000 rpm.c) Makeup Pump 2 in service.d) CCW Pump 1 in service.2) Hang "Do Not Operate" tags on Makeup Pump 1 and its oil pumps.a) Place on status board: Makeup Pump 1 is OOS at 0600 (present date) for pump outboard bearing replacement.
* Hang T.S. sheet for Makeup Pump 1 inoperable.
: 3) Hang "Do Not Operate" tags on TPCW Pump 1.a) Place on status board that TPCW Pump 1 is OOS at 0700 (present date)for preventative maintenance.
: 4) Hang the Chemistry sheet on the status board.5) Post Protected Train 2 signs.6) Initial malfunctions.
a) Rack out Makeup Pump 1 and its oil pumps -IRF B2M1 B TRUE, IRF B2M1A RACKOUT, IRF BME5A OPEN, IRF BME5D OPEN and IRF BME51 OPEN.b) Rack out TPCW Pump 1 -IRF KDP1 B REMOVE and IRF KDP1A RACKOUT c) Fails SFRCS to automatically to trip -IMF F300 10 of 12
: b. Procedures
: 1) For Crew: a) DB-OP-06901, Power Operations Procedure signed off appropriately to Step 3.6.2.b) DB-OP-06224, Main Feed Pump and Turbine Procedure signed off to Step 3.6.32.c) DB-OP-06401, Integrated Control System Operating Procedure.
d) DB-OP-06221, Condensate System Procedure.
e) DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure.
f) DB-OP-06006, Makeup and Purification System Procedure.
: 2) For Simulator Instructor:
a) DB-OP-06224, Main Feed Pump and Turbine Procedure.
: c. Event Triggers 1) Activates event 8 on a reactor trip -TRGSET 8 "LIZGlAPI(1)
< 50" d. Events 1) Shear the shaft on Condensate Pump 1 -IMF FAK40 (3)2) Fail high Steam Generator 2 Outlet Pressure Instrument, PT SP12A2 -IMF L1T334 (4) 1.0 30 0.74 3) Leak into CCW System from Letdown Cooler 1 -IMF BME1 B (5) 0.5 300 0.0 (Remove failure after letdown has isolated.)
: 4) Slow mid-scale failure of Loop 2 T-hot instrument
-IMF L1T6H (6) 0.5 10:00 0.74 5) FW 779 and FW 780 fail close -IMF FAAWB (7) and IMF FAB4B (7)6) Pressurizer code safety fails open on reactor trip -IMF HV40C (8)7) Fail open Startup Valve FW SP7A -IMF FAAZC (8)2. Cues (Non-generic)
: a. Event 1 and 2.11 of 12
: 1) None.b. Event 3 1) EO will report after the crew has identified the event that he heard a loud bang and found a broken coupling on Condensate Pump 1.c. Event4 1) None.d. Event5 1) None.e. Event 6 1) None.f. Event 7, 8 & 9 1) None.12 of 12 CHEMISTRY ANALYSES STATUS PR'NLARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/?11999 Date: 9/?/1999 Daily Average Limits Value Limits Value<100 02 <2 ppb 5 02 0.9 ppb150 Cl- 4.42 ppb 220 N 2 H 4  32.9 ppb<150 F- 2.35 ppb <20 SiO 2  <5 ppb Li 2.20 ppm <3 Na <0.1 ppb pH 6.88 ( 10 Fe <10 ppb 25-50 H 2  35.8 cc/kg <5 Cl- 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 (<100 TDG 37.8 cc/kg Measured H+Cond. 0.425 PS/cm<1.0 DEI-131 1.13E-2 giCi/gm 0.2 **Inorganic H+Cond. 0.06 RS/cm 100/E Specific Act. 0.461 gCi/ml Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 jiCi/ml **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)_ _ _ _ _ _ _ _ ____ ____ COVER GAS _ _ _ _ _ _ _ _ _ _ _ _ _ _Tank %H 2  %02 &deg;/0N 2  Time Date WGST CWRT 1 CWRT 2 ll BORON Primary to Secondary Leakage Vessel PPM Time Date RCS ? 0830 9/?/1999 <5.0 GPD (LLD is 5.0 GPD)PZR ? 1220 9/?/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST BasedonRCSXe-133 1.31E-2 jtCi/ml BAAT 1 Based on FI 1002 25 cfm lBAAT 2 _ RE 1003A RE 1003B CWRT 1 5 GPD cpm cpm CWRT 2 30 GPD cpm cpm CFT 1 100 GPD cpm cpm CFT 2 150 GPD cpm cpm SFP Increase of Refuel Canal 60 GPD cpmT_ cpmt Reviewed by Shift Supervisor Time/Date/
TECH SPEC STATUS Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.1.2.4 91?11999 Makeup pump 1 due to pump Restore to operable status by 72? outboard bearing replacement.
hours.Expires 91?11999 @ ?July 20, 1999 5: \OPS_GENERAL\Turnover Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 3 Op-Test No.: 1 Examiners:
_ Operators:
Objectives:
The RO candidates are to (1) perform the Weekly T-G Overspeed Trip Mechanism Test, (2)reduce reactor power to < 80% to recover a dropped control rod in Group 7, (3) manually control both main feedwater pump turbines due to FW valve AP instrument failing high, (4) start the standby TPCW pump, (5) start Makeup Pump 2 due to Makeup Pump 1 tripping, (6) minimize the iniection of BWST inventory due to makeup tank level failing low, (7) recover an essential bus due to a loss of power and (8) actuate SFRCS at the component level.Turnover:
10 qpd tube leak on Steam Generator
: 2. Planned: Weekly T-G Overspeed Trip Mechanism Test. Equipment out of service: EDG 1 to change out contaminated lube oil, SAC 1 for PMs.Event Malf. No. Event Event No. Type* Description 1 N(BOP) Perform Weekly T-G Overspeed Trip Mechanism Test.2 IMF KDP213 C(BOP) Turbine Plant Cooling Water Pump 2 trips.TRUE 3 IMF L110B R(RO) Drop a control rod in Group 7 (Rod 1).TRUE 4 IMF LITSH I(BOP) Feedwater valve AP instrument, PDT SP5B1, fails low after 0.0 Control Rod 7-1 has been recovered and ICS is full automatic.
5 IMF B2M1I C(RO) Trip Makeup Pump 1.TRUE 6 IMF B2L1 J I(RO) Both makeup tank level indicators fail low after pressurizer level TRUE control and seal injection flow have been reestablished.
IMF B2L2J TRUE 7 IMF P1Z7 M(AII) After the power reduction has been started a loss of off-site TRUE power occurs.8 IMF G528B C(RO) EDG 2 breaker trips on generator differential with a 30 second TRUE time delay.9 IMF F300 C(BOP) SFRCS fails to automatically or manually actuate.TRUE* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 1 & 2 Page 1 of 1 Event
 
== Description:==
 
Perform Weekly T-G Overspeed Trip Mechanism Test.Turbine Plant Cooling Water Pump 2 trips.Time Position Applicant's Actions or Behavior SRO Direct the implementation of DB-SS-04153, Weekly T-G Overspeed Trip Mechanism Test.BOP Perform DB-SS-04153, Weekly T-G Overspeed Trip Mechanism Test.BOP Identify that Turbine Plant Cooling Water Pump (TPCW) 2 has tripped.-Annunciator Alarm 11-1-F, TPCW HI LVL TK LVL-TPCW Pump 2 breaker indicates open, AD 206.BOP Perform the immediate actions of DB-OP-02514, Loss of Turbine Plant Cooling Water Pump(s).-Start the standby TPCW pump.SRO Direct the Implementation of DB-OP-02514, Loss of Turbine Plant Cooling Water Pump(s).-Verify the immediate actions.-When TPCW high level tank level has been restored, return to normal operations.
4 4 4+ 4+.1- I+ I I- I I-4.4.4-2 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 3 Page 1 of 1 lEvent
 
== Description:==
 
Drop a control rod in Group 7 (Rod 1).[ Time Position Applicant's Actions or Behavior RO Identify that Control Rod 7-1 has dropped into the reactor core.-Annunciator 5-1-E, CRD LCO-Annunciator 5-2-E, CRD ASYMMETRIC ROD-ASYM ALARM light on the Pi panel-ASYMMETRY FAULT light on rod control panel SRO Direct the implementation of DB-OP-02516, CRD Malfunctions
-RO to reduce reactor power to 60% using DB-OP-02501, Rapid Shutdown.-RO to transfer the affected control rod to the auxiliary power supply using DB-OP-06402, CRD Operating Procedure, Section 4.1.-Have the cause of dropped control rod investigated by l&C.-RO to control reactor power using DB-OP-06402, CRD Operating Procedure, Section 4.3, if necessary.
-RO to jog Control Rod 7-1 to de-energize phases to allow l&C checks.-RO to restore rod to group average per DB-OP-06402, CRD Operating Procedure.
-RO to transfer the affected control rod to the normal power supply using DB-OP-06402, CRD Operating Procedure, Section 4.2.RO Reduce reactor power to 60%.BOP Shutdown one of the running condensate pumps.RO Transfer Control Rod 7-1 to the auxiliary power supply using DB-OP-06402, CRD Operating Procedure, Section 4.1.RO Maintain reactor power using DB-OP-06402, CRD Operating Procedure, Section 4.3, if l _ necessary.
RO Jog Control Rod 7-1 to de-energize phases to allow l&C checks.RO Restore rod to group average per DB-OP-06402, CRD Operating Procedure.
-Latch and PI reset Control Rod 7-1 per Section 4.8.-Realign Control Rod 7-1 to the group average.-Verify that reactor power does not exceed power limits.RO Transfer the affected control rod to the normal power supply using DB-OP-06402, CRD Operating Procedure, Section 4.2.I I 1i t t I-*1 1- +3 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: I Scenario No.: 3 Event No.: 4 Page 1 of 1 Event
 
== Description:==
 
Feedwater Valve AP, PDT SP5B1, fails low after Control Rod 7-1 has been recovered and ICS is full automatic.
Time Position Applicant's Actions or Behavior BOP Identify Feedwater Valve AP, PDT SP5B1, has failed low.-Annunciator alarm 14-4-E, ICS INPUT MISMATCH-Annunciator alarm 12-5-A, SG 1 OR 2 FW VLV AP LO-Feedwater Valve AP indicator, PDI SP5B, fails low SRO Direct the operators to perform the following:
-BOP to place both main feedwater pump ICS stations into hand per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.16.-BOP to select the alternate feedwater valve AP instrument per DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure, Section 4.1.-BOP to place both main feedwater pump ICS station into automatic per DB-OP-06401, Integrated Control System Operating Prbcedure, Section 3.7.BOP Place both main feedwater pump ICS station into hand per DB-OP-06401, Integrated Control System Operating Procedure, Sectioh 3.16.BOP Select the alternate feedwater valve AP instrument per DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure section 4.1.BOP Place both main feedwater pump ICS station into automatic per DB-OP-06401, Integrated Control System Operating Procedure, Section 3.7.4 +I +I 1'1 .1.1 4.* I 4 I +1 4.4 +4 +4 +4 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 5 Page 1 of I1 Event
 
== Description:==
 
Trip Makeup Pump 1. j Time Position l Applicant's Actions or Behavior l RO Identify that Makeup Pump 1 has tripped.-Annunciator alarm 6-5-C, SEAL INJ FLOW LO.-Annunciator alarm 6-6-C, SEAL INJ TOTAL FLOW.-Makeup Pump 1 breaker indicates open, AC 105.RO Verify immediate actions of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify CCW to the RCPs.SRO Direct the implementation of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-Verify immediate actions.-Route to DB-OP-02512, Loss of RCS Makeup.SRO Direct the implementation of DB-OP-02512, Loss of RCS Makeup.-Verify immediate actions.-RO to close RCP Seal Injection Flow Control Valve, MU1 9 and Pressurizer Level Control Valve, MU 32.-RO to start the Makeup Pump 2.-RO to re-establish seal injection flow using MU19.-RO to restore pressurizer level control to automatic using MU 32.RO Close RCP Seal Injection Flow Control Valve, MU19 and Pressurizer Level Control Valve, MU 32.l_ _ Critical Task: 022-AA1.09 3.2/3.3 RO Re-establish a seal injection flow to the RCPs using MU19 per DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation.
RO Restore Pressurizer Level Control Valve, MU 32, to automatic.
I t I 1~ i I t r i I i 1 I 1-_t i 5 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Page 1 of 1 Event
 
== Description:==
 
Both makeuD tank level indicators fail low after pressurizer level control and seal injection flow have been maefntHlichad.
Time Position J Applicant's Actions or Behavior ]RO Identify that both makeup tank level indicators have failed low.-Annunciator alarm 2-2-C, MU TK LVL LO.-Makeup tank level indicators LR MU16 and LI MU16-2.-Makeup Pump Suction Valves, MU 3971 and MU 6405, transfer to the BWST position.SRO Direct the operators to perform the following:
-Minimize RCS makeup flow.-RO to reduce seal injection flow to minimum.-RO to close the Letdown Isolation Valve, MU 2B.-RO to place Pressurizer Level Control Valve, MU32, into hand and reduce demand to zero.-RO to reduce reactor power to keep Control Rod Group 7 off the out limit per DB-OP-02501, Rapid Shutdown or DB-OP-06902, Power Operations Procedure.
RO Reduce seal injection flow to minimum of 3 gpm/pump.RO Close the Letdown Isolation Valve, MU 2B.RO Place Pressurizer Level Control Valve, MU32, into hand and reduce demand to zero.RO Reduce reactor power to keep Control Rod Group 7 off the out limit.+ II4 4 4 4 6 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 7. 8 & 9 Page 1 of 2 Event
 
== Description:==
 
After the power reduction has been started a loss of off-site power occurs.EDG 2 breaker trips on generator differential.
SFRCS fails to automatically or manually actuate.Time J Position Applicant's Actions or Behavior All Identify the loss of off-site power.SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture:-Verify immediate actions.-RO to verify that buses C1 and Dl are de-energized.
-Route to DB-OP-02521, Loss of AC Bus Power Sources until Cl or DI bus___ _ re-energized.
RO Verify that buses CG and Dl are de-energized.
SRO Direct the implementation of DB-OP-02521, Loss of AC Bus Power Sources:-BOP to verify proper SFRCS response.-RO to close Letdown CIrs. Outlet, MU3, RCP Seal Return, MU 38, and Pzr Sample Line iso. Vlv., RC 240B.-RO to open Makeup Pump 2 breaker.-RO to re-energize buses Cl and/or Dl.-Route to Step 4.6 of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture.BOP Verify proper SFRCS response, which will require individual components to be repositioned.
-Open AFPT Steam Emission Valves, MS5889A and MS5889B-Close Main Steam Isolation Valves, MS100 and MS101.l Critical Task: 061-A3.01 4.2/4.2 4 .1 1 1 4 4 I I 4 4 I t I I 7 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 7, 8 & 9 Page 2 of 2 Event
 
== Description:==
 
After the power reduction has been started, a loss of off-site power occurs.EDG 2 breaker trips on generator differential.
SFRCS fails to automatically or manually actuate.Time Position Applicant's Actions or Behavior RO Verify the following valves closed.-Close Letdown Clrs. Outlet, MU3.-RCP Seal Return, MU 38.RO Open Makeup Pump 2 breaker.RO Re-energize buses C1 and/or Dl.Critical Task: 064-A4.06 3.9/3.9 SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture, from Step 4.6:-RO to start Makeup Pump 2.-BOP to re-establish control of atmospheric vent valves.RO Start Makeup Pump 2.BOP Re-establish control of atmospheric vent valves.Termination criteria:-Cl and/or D1 have been re-energized.
-Normal post trip secondary conditions on AFW.-Normal post trip primary conditions on natural circulation.
8 of 12 Justification for Critical Tasks A. Close the RCP Seal Injection Flow Control Valve, MUl9.Failure to close the RCP Seal Injection Flow Control Valve, MU19, when Makeup Pump 2 is started will result in pressure shocking of the RCP seals. This can lead to multiple RCP seal failure and increased RCS leakage. Closing the RCP Seal Injection Flow Control Valve, MU19, will prevent RCP seal damage when Makeup Pump 2 is restarted.
B. Establish proper SFRCS response by placing individual components in the SFRCS positions.
A failure of the SFRCS to automatically or manually actuate will result in a total loss of all feedwater.
The operator must place each SFRCS component in its SFRCS position to re-establish auxiliary feedwater cooling of the steam generators.
C. Re-energize Buses C1 and/or D1.All loss of off-site power and Buses C1 and D1 will result in a loss of RCS inventory control. Re-energizing Buses C1 and/or D1 will restore power to ECCS equipment.
9 of 12 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -100% power with summer time conditions.
: 2) Place SAC 1 control switch in lockout and hang a Red tag on the control switch.a) Place on the status board that SAC 1 is OOS for PMs.3) Hang Red tags on EDG 1 start pushbutton and AC101 breaker switch.a) Place on status board:* EDG 1 is OOS at three hours prior the start of the scenario for changing out contaminated lube oil. ,* Hang the T. S. sheet for EDG 1 inoperable.
* DB-SC-03070 is due the same time as the EDG 1 was listed as inoperable but on the next day.* DB-SC-03023 is due four hours after the start of the scenario on the present day.* DB-SC-04000 is due four hours after the start of the scenario on the present day.* DB-SC-04271 was completed seven days prior.4) Hang the chemistry sheet on the status board.5) Post Protected Train 2.6) CAEP file.a) Load the batch file -BAT TEMP\SCEN3.TXTIOO:00:0510 b) Delete dropped rod malfunction
-DMF L110BI04:00:00I1
: 7) Initial malfunctions.
a) Rack out SAC 1 -IRF KFS1A RACKOUT.b) Rack out AC01 -IRF G535A RACKOUT.c) Remove close power fuses from AC101 -IRF G535C REMOVE.10 of 12 d) Close EDG 1 air start motor air supply -IRF GD43 CLOSE and IRF GD44 CLOSE.e) Fail SFRCS to automatically and manually to trip -IMF F300, IMF F30AC, IMF F30BC, IMF F30CC and IMF F30DC.b. Procedures
: 1) For crew: a) DB-SS-04153, Turbine-Generator Overspeed Trip Mechanism Test with Step 3.2.2 signed off.b) DB-OP-06902, Power Operations.
c) DB-OP-06402, CRD Operating Procedure.
d) DB-OP-06401, Integrated Control System Operating Procedure.
e) DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure.
f) DB-OP-06006, Makeup and Purification System.c. Events 1) Trip TPCW Pump 2 -IMF KDP213 (2) TRUE.2) Drop Control Rod 7-1 -IMF L11OB (3).3) Fail Main Feedwater Valve Loop 1 AP low -IMF L1TSH (4) 0.0 30 0.44.4) Trip Makeup Pump 1 -IMF B2M11 (5).5) Both makeup tank level indicators fail low -IMF B2L1J (6) and IMF B2L2J (6).6) Loss of off-site power- IMF P1Z7 (7).7) Trip EDG 2 on a generator differential
-IMF G528B (7 30)2. Cues (Non-generic)
: a. Events 1 and 2 1) EO to report that breaker AD206 has a 50/51 relay actuated.2) Load Dispatcher will call to report a severe thunderstorm warning for Ottawa and Lucas counties.11 of 12
: b. Event 3 1) EO will report as necessary to support CRD operations.
: 2) I&C when sent to the CRD cabinets will report that during Group 7 movement that Phases A and B indicate blown fuses and someone has been sent to the warehouse for fuses. (Clear dropped rod malfunction using CAEP Line 2)3) I&C when told to check fuses will report that Phases BB and CC are energized and the four de-energized fuses have been checked. Fuses for Phases A and B were blown and replaced.4) I&C, when told the rod has been jogged in, will report that Phases AA and BB are energized and that remaining fuses are normal.c. Event 4 1) I&C will investigate instrument failure.d. Event 5 1) EQ sent to the MUP Room will report an electrical smell.2) EO sent to the MUP breaker will report that Phase A indicates an overcurrent.
: e. Event 6 1) I&C or EO sent to the makeup tank level instrument will report water dribbling out of the wall around one of the instrument lines.f. Event 7 1 ) None.12 of 12 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/?/1999 Date: 9/?/1999 Daily Average Limits Value Limits Value<100 02 <2 ppb <5 02 0.9 ppb<150 Cl- 4.42 ppb >20 N 2 H 4  32.9 ppb<150 F 2.35 ppb <20 SiO 2  <5 ppb* Li 2.20 ppm 3 Na <0.1 ppb pH 6.88 @ 10 Fe <10 ppb 25-50 H 2  35.8 cc/kg 5 Cl- 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 @<100 TDG 37.8 cc/kg Measured H+Cond. 0.425 iS/cm1.0 DEI-131 1.13E-2 RCi/gm 0.2 **Inorganic H+ Cond. 0.06 p.S/cm 100/E Specific Act. 0.461 ,uCi/ml Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 gCi/ml **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS Tank %H 2  %02 0/%N 2  Time Date WGST CWRT 1 CWRT 2 BORON _ Primary to Secondary Leakage Vessel PPM Time Date RCS ? 0830 9/?/1999 <5.0 GPD (LLD is 5.0 GPD)PZR ? 1220 9/?/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST Based on RCS Xe- 133 uiCi/ml BAAT 1 Based on FI 1002 cfln BAAT 2 RE 1003A RE 1003B CWRT 1 5 GPD cpm cpm CWRT 2 30 GPD cpm cpm CFT 1 100 GPD cpm cpm CFT 2 150 GPD cpm cpm SFP Increase of Refuel Canal 60 GPD cpml' cpml'Reviewed by Time/Date/Shift Supervisor TECH SPECT STATUS Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.8.1.1 91?/1999 EDG 1 due to changing out of Restore to operable status by 7 contaminated lube oil. days.Expires 9/?/1999 @ ?DB-SC-03070 due 9/?/1999 @At least once per 8 hours perform DB-SC-03023 due 91?11999 @At least once per 8 hours perform DB-SC-04000 due 91?/1999 @SB-SC-04271 completed 9/7/1999 July 20, 1999 5 : \\OPSGENERAL\Turnover Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse NPS Scenario No.: 4 Op-Test No.: 1 Examiners:
Operators:
Objectives:
The RO candidates are to (1) perform a transfer from four circ. water pumps operating to three circ. water pumps operatingc (2) lift off of low level limits, (3) place MU 32 into hand and transfer pressurizer level to a good instrument, (4)start SAC 1 due to a failure to automatically start when needed, (5) isolate letdown due to a steam generator tube leak and initiate a slant shutdown.
(6) stoD the steam Generators from overfilling.
(8) shutdown the plant using the SGTR EOP and trip the reactor, (9) manually trip the main turbine, and initiate HPI/MU/PORV cooling due a steam leak in the good steam generator.
Turnover:
10 qpd tube leak on Steam Generator
: 2. Planned: Switch from four circ. water pumps operating to three circ. water pumps operating for maintenance on Circ. Water Pump 4 and continue plant startup -lift off low level limits. Completed:
Maintenance on SAC 2 and returned to service, all testing of MDFP in the AFW mode .Equipment out of service: CCW Pump 2 for PMs and EDG 2 to change out contaminated lube oil.Event Malf. No. Event Event No. Type* Description 1 N(BOP) Switch from four circ. water pumps operating to three circ. water l_ pumps operating, shutdown Circ. Water Pump 4.2 R(RO) Raise reactor power from 28% to 35% to lift of low level limits.3 IMF H152C I(RO) Pressurizer level, LT RC14-2, fails low.TRUE 4 IMF KFS1G C(BOP) Trip Station Air Compressor 2 with a failure of Station Air TRUE Compressor 1 to automatically start after pressurizer level IMF KFS20 control has been reestablished.
TRUE 5 IM FATMD I(BOP) Deaerator Storage Tank 2 level, LT 420, control signal fails low.TRUE 6 IMF HH51 C(RO) Steam Generator 2 tube leak of 75 gpm builds over 10 minutes 0.015 after deaerator level has been restored to normal.7 IMF HH51 0.09 M(All) Steam generator tube rupture of 450 gpm after a plant shutdown has been started.8 N(AII) Rapid shutdown to low level limits.1 of 16 Appendix D Scenario Outline Form ES-D-1 9 IMF L7 EHC C(BOP) Turbine fails to trip with SFRCS failing to automatically actuate.TRUE IOR Al11AlAl9Sl-l OFF IMF FA300 TRUE 10 IMF SA05D 0.5 C(RO) Main steam safety valve on Steam Generator 1 sticks 20% open when reactor trips.* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 1 &2 Page 1 of 1 Event
 
== Description:==
 
Switch from four circ. water pumps operating to three circ. water pumps operating, shutdown Circ.Water Pump 4.Raise reactor power from 28% to 35% to lift off low level limits.Time Position Applicants Actions or Behavior SRO Direct the implementation of DB-OP-06232, Circulating Water System and Cooling Tower Operation, Section 4.12:-BOP to shutdown Circulating Water Pump 4.BOP Throttle the Discharge Valves on Circulating Water Pump 3 and 4.BOP Stop Circulating Water Pump 4 by pressing closed on the discharge valve.SRO Direct the implementation of DB-OP-06902, Power Operations:
-RO to place steam generator/reactor demand station to automatic per DB-OP-06401, Integrated Control System Operating Procedure.
-RO to lift off of low level limits.-BOP to throttle main feedwater pump flow to maintain a minimum of 3.8 MPPH.-RO/BOP to transfer Buses A and B from the startup transformer to the Aux. 11 transformer.
RO Adjust the unit load demand's rate of change to 30 MWe/min.RO Place steam generator/reactor demand station to automatic per DB-OP-06401, Integrated Control System Operating Procedure.
RO Adjust the unit load demand to raise reactor power 5% above the present value.RO Once the steam generators have lifted off low level limits then adjust unit load demand's rate of change to about 10 MWe/min.BOP Throttle the running main feedwater pump flow to maintain a minimum of 3.8 MPPH.RO/BOP Transfer Buses A and B from the startup transformer to the Aux. 11 transformer per DB-OP-06314, 13.8K Bus Switching.
3 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 3 Page 1 of 1 Event
 
== Description:==
 
Pressurizer Level. LT RC14-2, fails low. J Time l Position J Applicant's Actions or Behavior l RO Identify that pressurizer level, LT RC14-2, has failed low.-Annunciator alarm 4-1-E, PZRLOLVLHTRTRIP.
-Annunciator alarm 4-2-E, PZR LVL LO.RO Perform immediate actions:-Place MU 32, Pressurizer Level Control Valve, into hand.-Adjust MU 32 demand to obtain desired flow.Critical Task: 028-AA2.10 3.3/3.4 SRO Direct the implementation of DB-OP-02513, Pressurizer System Abnormal Operation:
-Verify immediate actions.-RO to manually control RCS pressure.-RO to transfer pressurizer level to a good instrument.
-RO to place MU 32, Pressurizer Level Control Valve, into automatic.
-RO to place pressurizer heater into automatic.
RO Manually control RCS pressure using pressurizer heaters.RO Transfer pressurizer level to a good instrument.
RO Place MU 32, Pressurizer Level Control Valve, into automatic.
RO Place pressurizer heater into automatic.
++.1. 4+ I 1- I+ I 4 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 4 Page 1 of 1J l Event
 
== Description:==
 
Trip Station Air Compressor 2 with a failure of Station Air Compressor 1 to automatically start after pressurizer level control has been reestablished.
l Time Position Applicant's Actions or Behavior RO/BOP Identify that Station Air Compressor 2 has tripped:-Annunciator alarm 9-2-E, STA AIR CMPSR 2 TRBLITRIP.
-Annunciator alarm 9-3-E, STA AIR HDR PRESS LO.-Annunciator alarm 9-1-F, INST AIR HDR PRESS LO.SRO Direct the implementation of DB-OP-02528, Loss of Instrument Air:-Verify immediate actions.-BOP to start Station Air Compressor 1 per DB-OP-06251, Station and Instrument Air System Operation Procedure, Section 5.1.BOP Start Station Air Compressor 1 per DB-OP-06251, Station and Instrument Air System Operation Procedure.
I 1 i t i I 4 I t-t 1 tt 1-t +1 1 T I 4 4 5 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 5 Page 1 of 1 Event
 
== Description:==
 
Deaerator Storage Tank 2 level, LT 420. control signal fails low.Time Position J Applicant's Actions or Behavior BOP Identify that Deaerator Storage Tank 2 level, LT 420, control signal has failed low:-Annunciator alarm 13-2-B, CNDS PMP DISCH HDR PRESS.-Annunciator alarm 13-3-B, CNDS PMP SUCT PRESS LO.-Deaerator storage tank level control valve, CD 420, is fully open.SRO Direct the following:
-BOP to place deaerator storage tank level controller, LIC 420, into hand and restore deaerator storage tank level to approximately eight feet.BOP Place deaerator storage tank level controller, LIC 420, into hand.BOP Restore deaerator storage tank level to approximately eight feet using an alternate level indication.
4 4 4 1 4 4 4 4 4 4+ I+ I+ 4+ 4 6 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 6 Page 1 of 1 Event
 
== Description:==
 
Steam Generator 2 tube leak of 75 gpm builds over 10 minutes after deaerator level has been restored to normal.Time Position J Applicant's Actions or Behavior RO/BOP Identify a Steam Generator 2 tube leak:-Annunciator alarm 9-4-A, VAC SYS DISCH RAD HI.-Annunciator alarm 12-1-B, MN STM LINE 2 RAD HI.-Decreasing makeup tank level with constant pressurizer level.SRO Direct the implementation of DB-OP-02531, Steam Generator Tube Leak:-RO to verify pressurizer level is being maintained.
-RO/BOP to determine that Steam Generator 2 has the tube leak.-RO to calculate leak rate.-Have Attachment 2, 3 and 4 performed.
-RO/BOP to start a plant shutdown per DB-OP-02504, Rapid Shutdown or DB-OP-06902, Power Operations.
RO Verify pressurizer level is being maintained.
RO/BOP Determine that Steam Generator 2 has the tube leak.RO Calculate leak rate using Attachment 1, Steam Generator Tube Leak Rate Calculation.
SRO Direct the implementation of DB-OP-02504, Rapid Shutdown or DB-OP-06902, Power Operations to start a plant shutdown.-RO to lower the reactor power by decreasing on the ICS unit load demand to force the plant back on to low level limits.RO Lower the reactor power by decreasing on the ICS unit load demand.I 4 I. 4 I. 4 I. I I. 4 7 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 7 & 8 Page 1 of 2 Event
 
== Description:==
 
Steam generator tube rupture of 450 qpm after a plant shutdown has been started.Rapid shutdown to low level limits.Time J Position [ Applicant's Actions or Behavior RO Identify that the Steam Generator 2 Tube leak rate has increased:
-Pressurizer level begins to lower.SRO Direct the implementation of DB-OP-02531, Steam Generator Tube Leak:-RO to close letdown Isolation valve, MU2B.-RO to start the second makeup pump per DB-OP-06006, Makeup and Purification System.-Route to DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Section 8.0, when the RO determines that pressurizer level is still lowering with all available makeup flow.RO Close Letdown Isolation Valve, MU2B.RO Start the second makeup pump per DB-OP-06006, Makeup and Purification System.RO Identify that pressurizer level is still lowering With all available makeup flow.I +I 1-4.1 4 I 4 I I 8 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 7 & 8 Page 2 of 2 Event
 
== Description:==
 
Steam generator tube rupture of 450 qpm after a plant shutdown has been started.Rapid shutdown to low level limits.Time Position l Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Section 8.0:-RO to lock makeup pump suctions on to the BWST.-RO to open CTMT Isolation for Alternate Injection Line, MU6421.-RO to control pressurizer level, > 100" if possible, using Pressurizer Level Control Valve, MU 32, and Alternate Injection Line Throttle Valve, MU6419.-RO/BOP to place the steam generator/reactor demand station into hand and reduce reactor power to low level limit if it is not already on low level limits.-Direct the auxiliary boiler to be started.-BOP to place both feedwater demands into hand and reduce them to zero.-BOP to place both turbine bypass valve controllers into hand and reduce turbine load to<5OMWe.-RO to trip the reactor.-BOP to trip the turbine.-Route to DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Step 3.2: RO Lock makeup pump suctions on to the BWST.RO Open CTMT isolation for alternate injection line, MU6421.RO Control pressurizer level, > 100" if possible, using Pressurizer Level Control Valve, MU 32, and Alternate Injection Line Throttle Valve, MU6419.RO/BOP Place the steam generator/reactor demand station into hand and reduce reactor power to low level limit if it is not already on low level limits.BOP Place both feedwater demands into hand and reduce them to zero.BOP Place both turbine bypass valve controllers into hand and reduce turbine load to < 50 MWe.RO Trip the reactor.BOP Trip the turbine.9 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 9 & 10 Page 1 of 3 Event
 
== Description:==
 
Turbine fails to trip with SFRCS failing to automatically actuate.Main steam safety valve on Steam Generator 1 is stuck open 20% when reactor trips.Time Position Applicant's Actions or Behavior BOP Identify that the turbine failed to trip.SRO Direct the BOP to trip SFRCS to initiate auxiliary feedwater and isolated the steam generators.
BOP Trip SFRCS to initiate auxiliary feedwater and isolated the steam generators.
Critical Task: E02-EA1.1 4.0/3.6.SRO Direct the implementation of DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Sections 3.0 and 4.0:-Verify the immediate actions.-Verify that SFRCS has been tripped to initiate auxiliary feedwater and isolated the steam generators due to the turbine failing to tnip. --Route to Section 7.0 for the Overcooling.
BOP Verify proper SFRCS.-Both auxiliary feedwater pumps running and feeding the steam generators.
-Have an EO transfer minimum recirc.SRO Direct the implementation of DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Section 7.0:-BOP to verify that SFRCS has terminate the overcooling after SFRCS has actuated on low steam pressure in Steam Generator 1.-BOP to manually align AFW System for a low steam pressure in Steam Generator 1.-Route to Step 8.7 for the steam generator tube rupture.BOP Identify that SFRCS has failed to align to terminate the overcooling after SFRCS has actuated on low steam pressure in Steam Generator 1.BOP Manually align AFW System for a low steam pressure in Steam Generator 1.-Open AF3869, AFP 1 to SG 2.Critical Task: E04-EK3.3-Close AF3870, AFP 1 to SG 1.BOP Manually align main steam to the AFW System.-Close MS106, Main Steam Line 1 to AFPT 1.-Close MS107A, Main Steam Line 1 to AFPT 2.BOP Manually control AW 2 and maintain RCS temperature constant or slightly decreasing.
10 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 9&10 Page 2 of 3 Event
 
== Description:==
 
Turbine fails to trip with SFRCS failing to automatically actuate.Main steam safety valve on Steam Generator I is stuck open 20% when reactor trips.Time Position Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-02000, RPS,SFAS, SFRCS Trip or SG Tube Rupture, Section 8.0:-RO to place HPI in the piggyback mode.-RO to depressurize the RCS to near the subcooling margin limit to allow the makeup and HPI to recover pressurizer level.-BOP to start a cool down to 5000F.-RO/BOP to establish MU/HPI cooling.RO Place HPI in the piggyback mode.-Lock makeup pump suction on the BWST.-Start standby CCW pump.-Start both HPI pumps.-Open HP 2A through D, HPI injection valves.-Start both LPI pumps.-Open piggyback valves, DH63 and DH64.Critical Task: 035-A2.01 4.5/4.6 RO Depressurize the RCS to near the subcooling margin limit to allow the makeup and hpi to recover pressurizer level.-Turn off all pressurizer heaters.-Block SFAS if not tripped and RCS pressure is under control.-Cycle RC 2 and pressurizer heaters to reduce and maintain RCS pressure near the subcooling margin limit.-Throttle makeup and HPI to maintain pressurizer level 80" to 120".BOP Cool down to 5000F.-Throttle AW 2 to maintain RCS cooldown rate at < I OOoF/hr.-If Steam Generator 2 level reaches 225" then cooldown rate limit can be increased to 2350F/hr.-At 5000F and 1000 psig in the RCS, stop the RCS cooldown.1- F t ti 1 -t I +i 1-It_________
________________
j __________________________________________________________________________
11 of 16 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 9&10 Page 3 of 3 Event
 
== Description:==
 
Turbine fails to trip with SFRCS failing to automatically actuate.Main steam safety valve on Steam Generator 1 is stuck open 20% when reactor trips.Time J Position Applicant's Actions or Behavior RO/BOP Coordinate the increase pressurizer level while maintaining the RCS cooldown rate as low as possible.RO Identify that the pressurizer has gone solid:-Sudden rapid pressure increase.RO Open PORV and high point vents:-Open PORV Block Valve, RC11.-Lock open PORV, RC2A.-Open High Point Vent Valves, RC4608A, RC4608B, RC461 OA, RC461 OB, RC200 and RC239A.Critical Task: 035-A2.01 4.5/4.6 Termination criteria:-Cooldown in progress to 5000F.-Subcooling margin > 20OF-Makeup and HPI have been throttle to control subcooling margin.4 -4 4 4+ I++ I 1*I 12 of 16 Justification for Critical Tasks A. Place Pressurizer Level Control Valve, MU32, into hand.Failure to Pressurizer Level Control Valve, MU32, into hand will result in the pressurizer filling solid.This will overpressurize the RCS. The operator must place the Pressurizer Level Control Valve, MU32, into hand and reduce makeup flow to regain control of the pressurizer level.B. Trip SFRCS to initiate auxiliary feedwater and isolate the steam generators due the main turbine failing to trip.A failure to trip SFRCS to initiate auxiliary feedwater and isolate the steam generators when the turbine fails to trip will result in both steam generators depressurizing and a cooldown of the RCS. The excessive overcooling caused by both steam generators could result in a restart accident.
The operator must trip SFRCS to initiate auxiliary feedwater and isolate the steam generators to prevent the excessive overcooling.
C. Align AFW System due to SFRCS failing to realign AFW System on low steam pressure in Steam Generator 1.A failure to realign the AFW system to isolate Steam Generator 1 will result in excessive overcooling of the RCS. The excessive overcooling can result in exceeding the pressure and temperature limits of the RCS and restart accident.
The operator must isolate AFW to Steam Generator 1 to eliminate the overcooling.
D. Establish MU/HPI cooling.A failure to establish MU/HPI cooling will result in a loss of BWST inventory due to continued steaming of the ruptured steam generator.
The loss of the BWST inventory will result in inadequate inventory to establish long term cooling. The operator must establish MU/HPI cooling to prevent a loss of BWST inventory.
13 of 16 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -28% power with reactor startup in progress with: a) MFPT 2 in service.b) CCW Pump 3 in service for CCW Pump 2.2) Hang a Red tag on the CCW Pump 2 breaker control switch.a) Place on the status board that CCW Pump 2 is OOS at 0300 on the present day for PMs 3) Hang Red tags on EDG 2 start pushbutton and AD101 treaker switch.a) Place on status board: EDG 2 is OOS at three hours prior the start of the scenario for changing out contaminated lube oil.* Hang the T. S. sheet for EDG 2 inoperable DB-SC-03071 is due the same time as the EDG 2 was listed as inoperable, but on the next day.DB-SC-03023 is due four hours after the start of the scenario on the present day.* DB-SC-04000 is due four hours after the start of the scenario on the present day.* DB-SC-04271 was completed seven days prior.4) Hang the Chemistry sheet on the status board.5) Post Protected Train 1.6) Place computer point H300 on a trend recorder.7) CAEP file.a) Prevent the turbine from tripping -SET "TFL7STOV=1"100:00:0510.
14 of 16 8)b. Procedure 1)b) Load the batch file -BAT TEMP\SCEN4.TXTIOO:00:10I1.
c) 450 gpm SGTR on SG 2 -IMF HH51 0.09104:00:0012 Initial malfunctions.
a) Rack out CCW Pump 2 -IRF KA34B REMOVE and IRF KA34A RACKOUT.b) Rack out AD101 -IRF G536C REMOVE and IRF G536A RACKOUT.c) Close EDG 2 air start motor's air supply -IRF GD45 CLOSE and IRF GD46 CLOSE.d) Prevent turbine manual trip pushbutton from tripping the turbine -IOR Al1AlA19S1-1 OFF.e) Fail SFRCS to automatically to trip -IMF F300 s For Crew: a) DB-OP-06232, Circulating Water System and Cooling Tower Operatiol b) DB-OP-06902, Power Operations signed off up to Step 3.1.7 c) DB-OP-06401, Integrated Control System Operating Procedure.
d) DB-OP-06407, Non-Nuclear Instrumentation System Operating is.Procedure.
e) DB-OP-06251, Station and Instrument Air System Operating Procedure.
: 2) For Simulator Instructor:
a) DB-OP-06232, Circulating Water System and Cooling Tower Operations.
: c. Event Triggers 1) Activates Event 8 on a reactor trip -TRGSET 8 "LIZGlAPI(1)
< 50".d. Events 1) Fail pressurizer level low -IMF H152C (3).2) Trip SAC 2 with a failure of SAC I to auto start -IMF KFS1G (4) and IMF KFS20 (4).15 of 16
: 3) Fail Deaerator 2 level low -IMF FATMD (5).4) 75 gpm SG 2 tube leak -IMF HH51 (6) 0.015 600 0.0 5) Fail a MSSV on SG 1 to 20% open on a reactor trip -IMF SA05D (8) 0.5.2. Cues (Non-generic)
: a. Event 1 and 2.1) EO to support the pre-brief and shutdown of Circ. Water Pump 4 as necessary.
: 2) Chem Lab will report that they have completed all necessary preparations for the shutdown of Circ. Water Pump 4.3) Load Dispatch will request a power increase rate of 10 MWe/minute as agreed to with DB management.
: b. Event 3 1) I & C to investigate the instrument failure.c. Event 4 1) EO sent to SAC 2 will report a trip on low oil pressure.d. Event 5 1 ) I & C to investigate the instrument failure.e. Event 6 1 ) None.f. Event 7 & 8 1 ) EO working on MDFP will report back when MDFP is aligned to the AFW mode.2) EO sent to MDFP will report that there are no indications of a problem with the breaker.g. Event 9 & 10 1) None.16 of 16 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 9/?/1999 Date: 91?/1999 Daily Average Limits Value Limits Value<100 02 <2 ppb <5 02 0.9 ppb<150 Cl- 4.42 ppb 220 N 2 H 4  32.9 ppb<150 F- 2.35 ppb <20 SiO 2  <5 ppb* Li 2.20 ppm <3 Na <0.1 ppb pH 6.88 @ 10 Fe <10 ppb 25-50 H 2  35.8 cc/kg <5 Cl- 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 @<100 TDG 37.8 cc/kg Measured H+Cond. 0.425 pS/cm<1.0 DEI-131 1.13E-2 .tCi/gm <0.2 **Inorganic H+ Cond. 0.06 gS/cm 100/E Specific Act. 0.461 .LCi/ml Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 RCi/ml **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS lTank %H 2  %02 l %N 2  Time Date WGST CWRT 1 CWRT 2 BORON _ Primary to Secondary Leakage Vessel PPM Time Date RCS ? 0830 9/?/1999 <5.0 GPD (LLD is 5.0 GPD)PZR ? 1220 9/?/1999 RE 1003 AIB Equivalent cpm for OTSG Leakage BWST Based on RCS Xe-133 1.31E-2 ,uCi/ml BAAT 1 Based on FI 1002 25 cfm BAAT 2 RE 1003A RE 1003B CWRT 1 5 GPD cpm cpm CWRT 2 30 GPD cpm cpm CFT 1 100 GPD cpm cpm CFT 2 _ __ 150 GPD cpm cpm SFP Increase of Refuel Canal 60 GPD cpml_ cpml Reviewed by.Time/Date/Shift Supervisor TECH SPC STATU Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.8.1.1 91?/1999 EDG 2 due to changing out of Restore to operable status by 7 contaminated lube oil. days.Expires 91?11999 @ ?DB-SC-03071 due 91?11999 @At least once per 8 hours perform DB-SC-03023 due 91?/1999 @At least once per 8 hours perform DB-SC-04000 due 91?11999 @SB-SC-04271 completed 9/7/1999 i & L July 20, 1999 5:\OPS_GENERAL\Turnover Appendix D Scenario Outline Form ES-D-1 Facility:
Davis Besse NPS Examiners:
Scenario No.: 5 Op-Test No.:_Operators:
Objectives:
The RO candidates are to (1) perform a power reduction from 100% to 93%for control rod testing (2) reduce reactor power to 72% and trip RCP 2-2 due to an oil leak, (3) control MFPT 1 manually on the MDT 20 due to the ICS demand failing to 100%, (4) control RCS pressure manually and transfer RCS pressure NNI input due to RCS pressure failina low, (5)transfer Steam Generator 2 operate level from the 'X' instrument to the 'Y' instrument due to the temperature compensation failing low. (6) triD the reactor due to a steam leak hito containment, (7) de-eneraize Buses E2 and F2 due to an ATWS. and (8) start the motor driven feed pump due to a loss of all AFW pumDs.= .Turnover:
Planned: Lower power to 93% for control rod exercising test and main turbine control valve testing. Equipment out of service: CCW Pump 3 for PMs, AFW Pump 2 for outboard pump bearng replacement.
Completed:
Maintenance and testina on CAC 2 breaker.Event l Malf. No. Event Event No. Type* Description 1 R(RO-P) Reduce reactor power from 100% to 93%.2 N(RO-P) Perform control rod exercising test after power has been reduced to 93%.3 IMF L1 S3N 1.0 I(RO-S) Downcomer temperature on Steam Generator
: 1. TT SP8A1 fails high after CRD Group 1 has been exercised.
4 IMF HU24 0.5 C(RO-P) Oil leak on RCP 2-2 upper reservoir after all ICS hand/auto stations have been restored to automatic.
5 IMF SFR5A C(RO-S) ICS demand to Main Feedwater Pump 1 fails to 100% after 5300 RCP 2-2 has been tripped and the plant is stable.6 IMF L4P2D I(RO-P) RCS Loop 1 pressure, PT RC2B2 fails low after manual control TRUE of MFP 1 has been established and the MFP flows are balanced.7 IMF SAM2 0.05 M(AII) A 5% steam leak on Steam Generator 2 into containment develops after the pressurizer heaters have been restored to automatic.
8 IMF L4 TRUE C(RO-P) An ATWS occurs that prevents CRD breakers from opening.9 IMF SFE8B C(RO-S) MS 106, Steam Generator 1 to AFPT 1, fails to open.TRUE* (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 1 & 2 Page 1 of 1 Event
 
== Description:==
 
Reduce reactor power from 100% to 93%.Perform control rod exercising test after power has been reduced to 93%.Time Position Applicant's Actions or Behavior SRO Directs the implementation of DB-OP-06902, Power Operations:
-Inform Chem. lab and Load Dispatcher
-RO to reduce power to 93%.RO Reduce power to 93%.SRO Direct the implementation of DB-SC-03272, Control Rod Exercising Test:-RO to transfer reactor demand to hand and rod control panel to manual-RO to transfer Control Rod group 1 to the auxiliary power supply.-RO to exercise Control Rod Group 1.-RO to transfer Control Rod Group I to the normal power supply.RO Transfer reactor demand to hand and rod control panel to manual RO Transfer Control Rod Group 1 to the auxiliary power supply per DB-OP-06402, CRD Operating Procedure, Section 4.1.RO Exercise Control Rod Group 1.RO Transfer Control Rod Group 1 to the normal power supply per DB-OP-06402, CRD Operating Procedure, Section 4.2.I+ 4.I+ 4 1- t I*1- t 4. 1 1- 1 4., 1 I I 2of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 3 Page 1 of 1 Event
 
== Description:==
 
Downcomer temperature on Steam Generator 1 TT SP8B1 fails high after CRD Group 1 has been exercised.
Time Position Applicant's Actions or Behavior BOP Identify that downcomer temperature on Steam Generator 1 has failed high.-Annunciator alarm 12-3-ASG 1 OPERATE LVL HI.-Annunciator alarm 14-4-E, ICS INPUT MISMATCH SRO Direct the implementation of DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure:
-BOP to place both feedwater demand stations into hand and both Loop 1 feedwater valve ]CS control stations into hand.-BOP to transfer downcomer temperature on Steam Generator 1 to the Y instrument and transfer operate level on Steam Generator 1 to the Y instrument.
BOP Transfer downcomer temperature on Steam Generator 1 to the Y instrument.
BOP Transfer operate level on Steam Generator 1 to the Y instrument.
4~1I+ 4 1-.1.4 4.4 4.4 4.3 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 4 Page 1 of 1 Event
 
== Description:==
 
Oil leak on RCP 2-2 upper reservoir after all ICS hand/auto stations have been restored to automatic.
Time Position Applicant's Actions or Behavior RO Identify that RCP 2-2 has a leak on the upper reservoir:
-Computer point, RCP 2-2 Upper Reservoir Level Low.-Annunciator Alarm 6-5-A, MONITOR SYSTEM TRBL, for high vibrations on RCP 2-2.SRO Direct the implementation of DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation:
-RO to transfer the rod control panel to automatic and reactor demand to automatic.
-RO/BOP to reduce power to 72% per DB-OP-02504, Rapid Shutdown.-RO to start RCP 2-2 lift pump and stop RCP 2-2.-BOP to verify that feedwater to the steam generators re-ratios.
-BOP to establish a zero AT-cold.-Contact I&C to verify high flux trip and flux/delta-flux/flow set points have been reduced.RO Transfer the rod control panel to automatic arid reactor demand to automatic.
RO Perform power reduction to 72% using ics unit load demand or by placing steam l _ generator/reactor demand station into hand.RO Maintain Imbalance
> -10% using axial power shaping rods.BOP Stop one of the condensate pumps when Condensate flow is < 7.0 MPPH.RO Start RCP 2-2 lift pump and stop RCP 2-2.BOP Verify that feedwater to the steam generators re-ratios.
BOP Establish a zero AT-cold by either using steam generator load ratio in hand or automatic.
.4. 4i.4. 4I_ I __ ____________
4 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 5 Page 1 of 1 Event
 
== Description:==
 
ICS demand to Main Feedwater Pump 1 fails to 100% after RCP 2-2 has been tripped and the plant is stable.Time Position Applicant's Actions or Behavior BOP Identify that MFP I ICS controller has failed to the high speed stop:-Annunciator alarm 10-2-F, BFP 2 DISCH FLOW LO.-MFP 1 speed increases to 5300 rpm.SRO Direct the recovery of MFP 1:-BOP to control MFP 1 using MDT-20 controller.
-BOP to balance the feedwater flow between the MFPs.BOP May place the MFP 1 ICS controller into hand and trying to reduce MFP 1 speed.BOP Match the MDT-20 controller to the ICS controller by increasing the MDT-20 controller and place the MDT-20 controller into service.BOP Using the MDT-20 for MFP 1, reduce flow on MFP 1 until it is matched with MFP 2.1-t 1 1I 1 t I I t t I t f I. t I 4 I1 I t i1*1 11-t t 5 of 12 Appendix D Operator Actions Form ES-D-2 I Op-Test No.: 1 Scenario No.: 5 EventNo.:
6 Page I of 1 Event
 
== Description:==
 
RCS Loop 1 Pressure.
PT RC2B2 fails low after manual control of MFP 1 has been established and the MFP flows are balanced.lTi Position Applicant's Actions or Behavior RO Identify RCS Loop I pressure transmitter has failed low:-Annunciator alarm 4-4-C, HOT LEG PRESS LO.-Annunciator alarm 5-1-G, RPS CH 1 TRIP.-Annunciator alarm 5-3-G, RPS RC LO PRESS TRIP.SRO Direct the implementation of DB-OP-02513, Pressurizer System Abnormal Operation:
-Verify immediate actions.-RO to manually control pressurizer heaters and spray.-RO/BOP to exchange RCS pressure inputs.-RO to restore pressurizer heaters to automatic.
-RO/BOP to place RPS channel 1 in bypass.RO Manually control pressurizer heaters and spray.RO/BOP Exchange RCS pressure inputs per DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure, Section 4.3 RO Restore pressurizer heaters to automatic.
RO/BOP Place RPS channel 1 in bypass using DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure, Section 4.5.I 1 t 1 i i-T I i1 t I I t I~ I 6 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 7.8 & 9 Page 1 of 3 Event
 
== Description:==
 
A 5% Steam Leak on Steam Generator 2 into Containment after the Pressurizer Heaters have been ractnrod fn niMmnfir,--1-111-1-ATWS that prevents CRD breakers from opening.Mgq 1 OR .0tAim r~cn~rqtnr 1 tn APPT 1 fnikc tn n Time Position Applicant's Actions or Behavior RO/BOP Identify the steam leak, into containment, on Steam Generator 2:-Annunciator alarm 4-4-A, CTMT TO ANNULUS AP HI/LO.-Annunciator alarm 4-3-A, CTMT NORM SUMP LVL HI.-Annunciator alarm 14-3-F, HPT MN STM PRESS.-Mismatch between MWe generated and reactor power.-Annunciator alarm 5-1-B, SFAS CTMT PRESS >18.4 PSIA CH TRIP.SRO Direct the implementation the Immediate Actions of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture, due to alarm 5-1-B:-RO to trip the reactor.-BOP to trip the turbine.RO Trip the reactor.BOP Trip the turbine.RO Identify that the reactor failed to trip:-Control rods fail to insert.-No annunciator alarm 8-1-A, CRD TRIP CONFIRM.SRO Direct the RO to de-energize and re-energize Buses E2 and F2.RO De-energize and re-energize Buses E2 and F2 and confirm control rods have inserted into the core.Critical Task: 029-EA1.1 1 3.9/4.1.1.I 1 1 I I 7 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: I Scenario No.: 5 Event No.: 7. 8 & 9 Page 2 of 3 Event
 
== Description:==
 
A 5% steam leak on Steam Generator 2 into containment after the Dressurizer heaters have been restored to automatic.
ATWS that prevent CRD breakers from opening.MS 106, Steam Generator 1 to AFPT 1, fails to open.Time Position Applicant's Actions or Behavior SRO Direct the implementation of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture:-BOP to stop all but one condensate pump.-RO to transfer makeup pump suctions to the BWST and start the second makeup pump.-BOP to start the motor drive feedwater pump and feed Steam Generator 1.-Route to Section 7.0, Overcooling, of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG l__.__.._Tube Rupture.BOP Stop all but one condensate pump.RO Transfer makeup pump suctions to the BWST.RO Start the second makeup pump.BOP Start the motor drive feedwater pump and feed Steam Generator 1.Critical Task: B&W E02.EA1.1 4.0/3.6-Enable both MDFP discharge valves and verify they are closed.-Start the MDFP.-Using the MDFP discharge valve to Steam Generator 1 establish flow.-Establish a level of about 49" in Steam Generator 1.4 4+ 4 I 1-1-I I 1-8 of 12 Appendix D Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 5 Event No.: 7, 8 & 9 Page 3 of 3 Event
 
== Description:==
 
A 5% steam leak on Steam Generator 2 into Containment after the pressurizer heaters have been restored to automatic.
ATWS that Prevent CRD breakers from opening.MS 106, Steam Generator 1 to AFPT 1, fails to open.Time Position l Applicant's Actions or Behavior SRO Direct the implementation of Section 7.0, Overcooling, of DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture:-RO/BOP to verify that the overcooling has terminated.
-BOP to take manual control of Steam Generator 1 AVV.-RO to depressurize the RCS to near the subcooling margin limit.-RO to borate the RCS.-BOP to maintain steam generator tube to shell differential temperature within limits.RO/BOP Verify that the overcooling has terminated.
BOP Take manual control of Steam Generator 1 AW.-Place AVV 1 into manual.-Block the SFRCS to AW 1 and depress auto.-Maintain RCS temperature constant or slightly decreasing.
RO Depressurize the RCS to near the subcooling margin limit.-Turn off all pressurizer heaters.-Cycle the pressurizer spray to reduce SCM to near the limit.-Block SFAS if RCS pressure under control.RO Borate the RCS.BOP Maintain steam generator tube to shell differential temperature within limits using AVV 1.Termination criteria:-Subcooling margin is being maintained near the limit.-RCS temperature is being maintained within the steam generator tube to shell differential temperature limit.-About 49" is being maintained in Steam Generator 1.9 of 12 Justification for Critical Tasks A. De-energizing Buses E2 and F2.Failure to de-energizing Buses E2 and F2 will result in overheating of the RCS and reactor core. The overheating could cause the RCS to rupture or damage to the reactor core. The operator must de-energizing Buses E2 and F2 to get the control rods to drop into the reactor core.B. Start the motor drive feedwater pump and establishing feed flow to Steam Generator 1.A failure to start the motor driven feedwater pump and establishing feed flow to Steam Generator 1 will result in overheating of the RCS. The overheating of the RCS could cause damage to the reactor core.The operator must start the motor driven feedwater pump and establishing feed flow to Steam Generator 1 to stop the RCS from overheating.
10 of 12 SIMULATOR SETUP AND CUES Simulator Setup a. Initial Conditions
: 1) -100% power, middle of life.2) Hang Red tags on both of CCW Pump 3 breaker switches.a) Enter on the status board that CCW Pump 3 is OOS for motor PMs.3) Hang Red tags on AF 3872, AF 3871, MS 107, MS 107A and AFPT 2 Governor Controller.
a) Enter on the status board: AFP 2 is OOS at 0600 on the present day for pump outboard bearing replacement.
* Hang T.S. sheet for AFP 2 inoperable.
: 4) Hang the Chemistry sheet on the Status board. Hang the Chemistry sheet on the status board.5) Post Protected Train 1.6) Initial malfunctions.
a) Prevent the reactor from tripping -IMF L4, IMF L8, IMF L5D2 and IMF L5D1.b) Fail MS line 1 to AFPT 1, MS 106 closed -IMF SFE8B.c) Tag out AFP 2 -IMF FKGFB, IMF SFECB, IRF FKGF FALSE, IRF FKGE FALSE, IRF SFECA OPEN and IRF SFE6A OPEN.b. Procedure 1)s For cres a)b)c)d)V: DB-OP-06902, Power Operations.
DB-SC-03272-Control Rod Exercising Test.DB-OP-06402, CRD Operating Procedure.
DB-OP-06403, Reactor Protection System and Nuclear Instrumentation Operating Procedure.
11 of 12 e)f)DB-OP-06401, Integrated Control System Operating Procedure.
DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure.
: c. Events 1) Fail SG 2 downcomer temperature low -IMF L1S3N (3) 1.0 60 0.86.2) RCP 2-2 upper reservoir leak -IMF HU24 (4) 0.5.3) ICS demand to MFPT 1 fail to 100% -IMF SFR5A (5) 5300.4) Fail RCS Loop 1 pressure low -IMF L4P2D (6).5) 5% steam leak on SG 2 into CTMT -IMF SAM2 (7) 0.05 2. Cues (Non-generic)
: a. Event 1 and 2.1) Role play as EO to support CRD power supply transfers.
: b. Event 3 1) I&C to troubleshoot problem with SG 1 downcomer temperature.
: c. Event4 1 ) None.d. Event 5 1) I&C and System Engineering to trouble shoot MFPT 1 problem.e. Event 6 1) I&C and System Engineering to trouble shoot RPS Ch. 1 RCS pressu ire f. Event 7, 1)transmitter.
8&9 EO sent to check MS 106 will report that the valve is jammed closed.12 of 12 CHEMISTRY ANALYSES STATUS PRIMARY (RCS) SECONDARY (FEEDWATER)
Time: 0830 Date: 91?/1999 Date: 9/?1l999 Daily Average Limits Value Limits Value<100 02 <2 ppb 5 02 0.9 ppbl150 Cl 4.42 ppb 20 N 2 H 4  32.9 ppb<150 F- 2.35 ppb <20 SiO 2  <5 ppb* Li 2.20 ppm 3 Na <0.1 ppb pH 6.88 @ 10 Fe <10 ppb 25-50 H 2  35.8 cc/kg <5 Cl- 0.07 ppb N 2  1.97 cc/kg 9.3 pH 9.82 @<100 TDG 37.8 cc/kg Measured H+Cond. 0.425 g.S/cm<1.0 DEI-131 1.13E-2 pCi/gm <0.2 **Inorganic H+ Cond. 0.06 itS/cm l100/E Specific Act. 0.461 giCi/ml Condensate Dissolved 02 3.2 ppb I-131 3.67E-3 IiCi/ml **Inorganic H+ Cond. is a calculated value* Per DB-CH-06900, Attachment 1 Highest Condensate Polisher AP: 1.02 psid (to nearest psid)COVER GAS Tank %H 2  %02 0/%N 2  Time Date WGST CWRT 1 CWRT 2 BORON Primary to Secondary Leakage Vessel PPM Time Date RCS ? 0830 9/?/1999 <5.0 GPD (LLD is 5.0 GPD)PZR ? 1220 9/?/1999 RE 1003 A/B Equivalent cpm for OTSG Leakage BWST Based on RCS Xe-133 _iCi/ml BAAT 1 Based on FI 1002 cfm lBAAT 2 RE 1003A RE 1003B CWRT 1 5 GPD cpm cpm CWRT 2 30 GPD cpm cpm CFT 1 100 GPD cpm cpm CFT 2 150 GPD cpm cpm SFP Increase of Refuel Canal 60 GPD cpm1 cpm1 Reviewed by Shift Supervisor Time/Date/
TECH SPEC STATUS Tech Date/Time Action Required/When Spec Entered Equip Name/Reason Remarks 3.7.1.2 9/?/1999 AFP 2/due to replacement of Restore to operable status within 9 pump outboard bearing 72 hours.l_ l_ l_ lExpires 9/?/1999 @ ?July 21, 1999 JS:\OPSGENERAL\Turnover INITIAL SUBMITTAL OF THE WRITTEN EXAMINATION FOR THE DAVIS-BESSE EXAMINATION THE WEEK OF SEPTEMBER 13, 1999 ES-401 Site-Specific Written Examination Cover Sheet Form ES-401-8 U.S. Nuclear Regulatory Commission Site-Specific Written Examination Applicant Information Name: KEY Region: I / II AI/ IV Date: Facility/Unit:
Davis-Besse NPS License Level: (R- / SRO Reactor Type: W / CE /l4W)/ GE Start Time: Finish Time: Instructions Use the answer sheets provided to document your answers. Staple this cover sheet on top of the answer sheets. The passing grade requires a final grade of at least 80.00 percent.Examination papers will be collected five hours after the examination starts.Applicant Certification All work done on this examination is my own. I have neither given nor received aid.Applicant's Signature Results Examination Value ..100 Points Applicant's Score Points Applicant's Grade Percent 43of 45 NUREG-1021, Revision 8 Question Number 1 The plant is operating in Mode 6 with fuel shuffle in progress.
The Control Room has received the following alarm: 3-1-A, Refueling Canal Level Refueling canal level is low and decreasing.
The Fuel Handling Director has directed you, the Main Fuel Handling Bridge Operator, to lower the fuel assembly in the mast to a safe location.
Which ONE of the following is an allowable location?a. Refueling Canal Racks b. Fuel Storage Handling Bridge Mast full down position c. CTMT Transfer Mechanism Upender in the horizontal position d. Main Fuel Handling Bridge Fuel Mast full up position Answer: c.
Question Number 2 The following plant conditions exist: Power history: 500 EFPD APSR position:
30% withdrawn The plant has experienced a reactor trip.Control Rod 3-2 failed to insert into the core.* Operational mode: Mode 4 Using DB-NE-06201, Reactor Operator Curve Book, determine the minimum RCS boron concentration to assure a 1% DK/K shutdown margin exists.a. 870 ppmB b. 930 ppmB c. 950 ppmB d. 1000 ppmB Answer: d.
Question Number 3 Which ONE of the following describes how the PORV is opened when RCS pressure reaches its lift setpoint?a. Steam pressure overcomes the spring pressure of the pilot valve, which opens and bleeds steam pressure from the inner chamber of the main disk, allowing the main disk to open.b. Steam pressure overcomes the spring pressure of the pilot valve, which opens and bleeds air pressure from the power operator to open the main disk.c. A pressure signal causes a solenoid to mechanically reposition the PORV disk by overcoming the pressure exerted by the closing spring.d. A pressure signal causes a solenoid to open the pilot valve which bleeds the steam pressure from the inner chamber of the main disk, allowing RCS pressure to open the main disk.Answer: d.
Question Number 4 The following plant conditions exist: Fuel handling operations are in progress.* Refueling canal level is 234".* DH Train 2 is in service.* DH Pump 1 is out of service for breaker repairs.Electricians working on the wrong breaker cause DH1A, DH Pump 2 Discharge to RCS, to close.Which ONE of the following is the next action to be taken?a. Suspend core alterations.
: b. Have an EO open DHIA.c. Have the electricians restore DH Pump 1 and start it.d. Evacuate containment.
Answer: a.
Question Number 5 The following plant conditions exist: One makeup pump is running.A reactor trip has just occurred.One rod in a safety group has failed to insert.All other rods are fully inserted.* Immediate actions for the reactor trip are complete.Which ONE of the following is the next action that must be accomplished after checking the condition of the control rods?a. Check for turbine trip.b. Commence boration from the BAAT.c. Start the second MU pump and shift suction to the BWST.d. Momentarily deenergize E2 and F2.Answer: a.
Question Number 6 The following plant conditions exist:* Reactor power is 40% and increasing.
Rod index is 265.* ROD CONTROL PANEL OUT COMMAND is constantly illuminated.
Which ONE of the following actions are required to be immediately performed?
: a. Trip the reactor using the RPS manual trip pushbuttons.
: b. Direct an EO to open the three CRD breakers in the Low Voltage Switchgear Rooms.c. Depress the ROD STOP pushbutton on the Control Rod Panel.d. Place the Rod Control Panel in manual and insert the control rod.Answer: c.
Question Number 7 DB-OP-03272, Control Rod Exercising Test, is in progress.The last control rod group has just been exercised."Auto" has been depressed on the Rod Control Panel with no response.Which ONE of the following would prevent the Rod Control Panel from returning to "Auto"?a. "Fault Reset" was NOT depressed after exercising the last group.b. Control Rod Group 3 rods are NOT at the "Out Limit".c. Control Rod Group 6 rods are NOT at the "Out Limit".d. The Out Inhibit lamp is illuminated.
Answer: b.
Question Number 8 Given the following conditions:
An RCS cooldown is in progress.The "1650 psig TRIP BLKD" lights have illuminated.
At 1700 psig, the operator bypasses the SFAS RCS low pressure bistable for all four channels.An RCP seal leak then develops, causing the operator to trip the affected RCP and increase the plant cooldown rate.* RCS pressure decreases to 1450 psig.Select the appropriate SFAS response: a. HPI initiates on low RCS pressure due to the RCS leak.b. The "Blue Safety System Bypass Lights" for HPI illuminate.
: c. LPI initiates on low RCS pressure due to the RCS leak.d. SFAS 1650 block prevents an SFAS Level 2 actuation.
Answer: d.
Question Number 9 The following plant conditions exist:* PZR PORV outlet temperature 255 0 F* PZR quench tank level 9.3 ft.* PZR quench tank temperature 215 0 F* RC PZR BONNET TEMP, PCV-RC13-1 180 0 F (Assume level and temperature control in automatic.)
Which ONE of the following is correct?a. Quench tank recirculating pump started on HIGH temperature caused by the leaking PORV and level is automatically being controlled by draining to the RC drain tank.b. Quench tank recirculating pump started on HIGH level caused by the leaking PORV and temperature is automatically being controlled by draining to the quench tank cooler.c. Quench tank recirculating pump automatically started to reduce HIGH temperature caused by the leaking PORV and level is automatically being controlled by draining to the containment sump.d. Quench tank recirculating pump has started automatically due to HIGH level caused by the leaking PORV and pressure is automatically being controlled by draining to the containment sump.Answer: a.
Question Number 10 The following sequence of events has occurred: The Main Turbine tripped at 35% reactor power.* Main Stop Valve 1 failed to close.* Main Control Valve 1 failed to close.After completion of the appropriate steps of DB-OP-02500, Turbine Trip, the plant status will be: a. reactor power at 28%, steam generator level control on low level limits, and steam generator pressure control on TBVs.b. reactor power at 0%, steam generator level control on low level limits, and steam generator pressure control on the MSSVs.c. reactor power at 28%, steam generator level control on auxiliary feedwater, and steam generator pressure control on TBVs.d. reactor power at 0%, steam generator level control on auxiliary feedwater, and steam generator pressure control on the MSSVs.Answer: d.
Question Number 11 The following plant conditions exist:* The plant is operating at 65% power.* A "lockout" condition has occurred on Essential 4160V Bus D1.* All plant systems have responded as designed.* No operator actions have been taken.Annunciator alarm (1-3-H) BUS D1 LOCKOUT is in alarm. Bus voltage will be a. 0 volts and Emergency Diesel Generator 2 will be running with the output breaker open.b. 0 volts and Emergency Diesel Generator 2 will have started and tripped.c. 4160 volts and Emergency Diesel Generator 2 will be running with the output breaker closed.d. 4160 volts and Emergency Diesel Generator 2 will have started and tripped.Answer: a.
Question Number 12 Given the following conditions:
* The plant has run back to 700 MWe and stopped.* Steam Generator 1 operate level is 66%.* Steam Generator 2 operate level is 27%.* A transfer of Tave instrument has occurred with both the X and Y SASS transfer switch lights lit.Which ONE of the following is the cause of the above conditions?
: a. A main feedwater pump has tripped.b. A main feedwater flow instrument has failed.c. A reactor coolant pump has tripped.d. A Reactor Coolant System flow instrument has failed.Answer: c.
Question Number 13 The following plant conditions exist: RCS unidentified leakage is 0.65 gpm and constant for one week.Pzr SCR heater bank demand is 100%.* Pzr Heater Bank 2 has been cycling four times per hour to maintain RCS pressure.* Current burnup is 652 EFPD on a 680 EFPD core.An instrument failure results in an overcooling event which has been terminated, and the plant has been stabilized at 88% power.The operator's next concern will be: a. Compensating for the amount of boron added to the RCS from the PZR.b. Restoring imbalance to the normal operations band.c. Adding boric aid to prevent control rod group 7 from reaching its out limit.d. Restore reactor power to 100% to prevent a xenon transient.
Answer: a.
Question Number 14 A reactor startup is in progress.The Reactor Operator has just completed withdraw of Control Rod Group 4 and was aligning the phases to transfer from the auxiliary power supply to the normal power supply. When he stopped moving Control Rod Group 4, three phases remained energized.
Which ONE of the following states why it is a concern that three phases are energized?
: a. Will result in heat damage to the reed switches in the absolute position indication stack.b. Heat generated in the stator is beyond the capacity of CCW flow supplied.c. Will result in heat damage to the roller nut assembly and prevent disengagement.
: d. Causes voiding in the CRD motor tube.Answer: b.
Question Number 15 A 75% power hold is in progress when the following sequence of events occur: Main Feedwater Pump 1 trips on low bearing oil pressure.* Plant has run back to 55%.The operator performs a comparison of NIP/HBP and identifies the relationship is above the required calibration line. (See Figure CC 6.9A of DB-OP-06703)
The reason for this out of calibration condition is due to a. NIP reads HIGH due to the increase in cold leg temperature
: b. NIP reads LOW due to the delayed neutrons that have not yet been born c. HBP reads HIGH due to decrease in feedwater temperature
: d. HBP reads LOW because Group 38 takes 6 minutes to update Answer: a.
Question Number 16 The plant was at 100% power when the following sequence of events occurred: RCP 2-2 upper bearing temperature alarm actuated.Power was reduced to 72%.* RCP 2-2 was stopped.Which ONE of the following sets of values is the expected seal injection flow rates? (All values given in gpm.)RCP RCP RCP RCP 1-1 1-2 2-1 2-2 a. 7.8 8.1 8.1 8.0 b. 6.6 6.8 6.4 12.2 c. 9.8 9.4 9.0 3.8 d. 7.7 7.9 8.2 4.5 Answer: c.
Question Number 17 The plant is operating in Mode 1 with four RCPs running. RCP 1-2 computer summary shows the following values for the seal pressures:
Second stage -1206 psig* Third stage -258 psig* Seal return flow- 2.1 gpm Which ONE of the following describes the next action to be taken?a. Close RCP 1-2 seal return valve.b. Increase monitoring of RCP 1-2 and maintain power.c. Verify reactor power is < 72% and trip RCP 1-2.d. Close RCP 1-2 seal injection valve.Answer: c.
Question Number 18 Which ONE of the following combinations describes the direction that the valves would move if the controlling pressurizer level instrument failed high with no operator action?MU 32 a. OPEN MU 19 OPEN b. CLOSE c. OPEN d. CLOSE Answer: d.OPEN CLOSE CLOSE Question Number 19 Refueling operations are in progress.Plant conditions are as follows: Fuel handling personnel report the Fuel Storage Handling Bridge just ran into the SFP wall with a spent fuel assembly in the mast.RE 5403C, Fuel Handling Exhaust System, is in alarm high.* RE 5403B, Fuel Handling Exhaust System, is in alarm high.In accordance with DB-OP-02530, Fuel Handling Accident Procedure, which ONE of the following is the next action to be taken?a. Sound the Containment Evacuation alarm and make an announcement to evacuate containment.
: b. Sound the Containment Evacuation alarm and make an announcement to evacuate the Radiologically Restricted Area.c. Have the Fuel Handling Director evacuate Containment and MANUALLY trip the Fuel Handling Ventilation System exhaust radiation monitors.d. Evacuate the SFP area and START both trains of Control Room Emergency Ventilation System.Answer: b.
-Question Number 20 High pressure injection flow balancing is required for which ONE of the following conditions?
: a. Two makeup pumps running and one HPI pump running during a LOCA.b. One makeup pump running and two HPI pumps running during an overcooling accident.c. Two makeup pumps running and one HPI pump running during feed and bleed core cooling.d. One makeup pump running and two HPI pumps running during a steam generator tube rupture.Answer: a.
Question Number 21 The plant is in a natural circulation cooldown when the following is observed: RCS pressure is 456 psig and slowly decreasing.
* Pressurizer level step changed from 80" to 110".Which ONE of the following is the set of actions to correct this situation?
: a. Increase RCS pressure until pressurizer level no longer decreases.
: b. Decrease makeup flow until pressurizer level no longer increases.
: c. Bump start an RCP.d. Increase letdown flow until pressurizer level is restored.Answer: a.
Question Number 22 The plant was operating in Mode 1 when a small break LOCA occurred.
All systems functioned normally, except #1 MUP failed to start.You observe the following indications:
* HPI flow on Fl-HP3A reads 450 gpm.* HPI flow on FI-HP3B reads 225 gpm.HPI flow on FI-HP3C reads 400 gpm.* HPI flow on Fl-HP3D reads 400 gpm.What is the reason for the flow disparity between Fl-HP3A and 3B?a. Fl-HP3A reads high because the leak is downstream of the transmitter on the HPI line.b. FI-HP3B reads low because the leak is upstream of the transmitter on the HPI line.c. Fl-HP3A reads high because the MU flow injects upstream of the transmitter.
: d. Fl-HP3B reads low because of MU flow injecting downstream of the transmitter.
Answer: d.
Question Number 23 Which ONE of the following prevents simultaneously placing two channels of the Reactor Protection System (RPS) in "Manual Bypass" during full power operations?
: a. An electrical interlock that causes a reactor trip (2 of 4 logic) when the second channel RPS channel is placed in "Manual Bypass".b. An administrative control that permits only one "Manual Bypass" key in the Control Room at any time.c. An electrical interlock that returns both channels to "Normal" when the second RPS channel is placed in "Manual Bypass".d. An electrical interlock that prevents more than one RPS channel from being placed in "Manual Bypass".Answer: d.
Question Number 24 Given the following conditions:
* A reactor trip has occurred from 100% power.* RCS pressure is 1165 psig.* T-hot is 565 0 F.* T-cold is 485 0 F.Select the instrumentation that should be used to check for adequate subcooling margin (SCM).a. T-ave and RCS loop pressure b. T-cold and RCS loop pressure c. T-sat meter with T-hot as the selected input d. Incore thermocouples and RCS loop pressure Answer: d.
Question Number 25 The following plant conditions exist:* A clean liquid radwaste release is in progress.* The liquid radwaste discharge radiation monitor, RE 1770A, is out of service.The primary equipment operator has just reported that the liquid radwaste discharge radiation monitor, RE 1770B, has developed a leak and was isolated.Which ONE of the following is the action that the Shift Supervisor must direct?a. Continue the liquid release; initiate two independent samples for analysis; initiate independent verification of release rate calculations; and initiate independent verification of release path.b. Continue the liquid release; initiate grab samples at least once every 12 hours for analysis of gross radioactivity; and initiate independent verification of release rate calculations and the release path.c. Stop the liquid release; resume the release after two independent samples are analyzed; and two independent verifications of release rate calculations and the release path are performed.
: d. Stop the liquid release; do NOT resume the release until at least one of the two liquid radwaste radiation monitors have been returned to operability.
Answer: c.
-Question Number 26 Which ONE of the following is the reason that long-term boron dilution flow must be established following a large LOCA?a. To prevent boron precipitation in the core from blocking flow through the lower support structure and the flow distributor.
: b. To prevent boiling in the core 7 days after the trip due to insufficient decay heat to maintain natural circulation.
: c. To prevent boron precipitation in at least one RCS loop in order to maintain one SG available for alternate decay heat removal.d. To prevent uneven boron distribution in the core that could allow localized criticality or loss of 1%shutdown margin.Answer: a.
Question Number 27 The following plant conditions exist: Plant cooldown to Mode 5 is in progress for a mid-cycle outage.* RCS temperature is 480 0 F.Reactor Engineering has informed the Shift Supervisor that due to errors in the Reactor Operator's Curve Book, the shutdown margin under present conditions is at 1.0% AK/K.A Turbine Bypass Valve (TBV) has failed open. Before the TBV can be isolated, RCS temperature has decreased to 460 0 F.What should be the next action taken?a. Have Safety Engineering confirm the errors in the Reactor Operator's Curve Book and shutdown margin.b. Borate at 12 gpm of 7875 ppm boron or equivalent until Reactor Engineering confirms shutdown margin is > 1.0% AK/K.c. Borate at 25 gpm of 7875 ppm boron or equivalent until Reactor Engineering confirms Keff is>0.99.d. Borate at 25 gpm of 7875 ppm boron or equivalent until Reactor Engineering confirms shutdown margin is > 1.0% AK/K.Answer: d.
Question Number 28 The plant is operating at 100% power, equilibrium conditions.
The air line to MU-32 ruptures, resulting in MU-32 failure. At what pressurizer level will action be required due to this failure? Assume no operator action has been taken.a. 100 inches b. 160 inches c. 290 inches d. 305 inches Answer: c.
Question Number 29 The following sequence of events has occurred:* Reactor trip.Immediate actions of DB-OP-02000 have been performed,* RO -Primary has been asked to verify all control rods have inserted.The RO -Primary observes that all the individual control rod position indication on the CRD position indication panel read at or near 100% and all 0% lights for all but APSRs are lit.The cause for this condition is: a. The reactor has failed to trip.b. The API/RPI switch has been left in the RPI position.c. All CRD position indicators, except APSR position indicators, have failed.d. A high voltage on the API circuit has caused the API indication to read erroneously.
Answer: b.
Question Number 30 The following plant conditions exist: Engineering has determined that CFT 1-2 Discharge Check Valves are leaking.* The CFT discharge isolation valve (CF-1A) has been closed and its breaker OPEN.Which ONE of the following is the action that the Shift Supervisor must direct?a. Be in at least HOT STANDBY within 6 hours and in COLD SHUTDOWN within the following 30 hours.b. Within 4 hours commence a shutdown to HOT STANDBY within 6 hours and in COLD SHUTDOWN within the following 30 hours.c. Continue power operations.
: d. Commence a shutdown to be in HOT STANDBY within 1 hour.Answer: d.
Question Number 31 The plant has experienced a LOCA with a loss of off-site power. Plant conditions are as follows: RCS pressure is 300 psig and constant.Average incore temperature is 689 0 F and rising NI 1 is 3.6 X 103 counts and rising.NI 3 is 10-11 amps and constant.EDG 1 has tripped on overspeed.
* HPI Pump 2 has been stopped due to a rupture at the pump's discharge piping.Which of the following would be the appropriate procedural guidance to find actions to mitigate the present plant conditions?
: a. DB-OP-02000, Section 10, Large LOCA b. DB-OP-02000, Section 9, ICC c. DB-OP-02000, Section 5, Lack of Subcooling Margin d. DB-OP-02521, Loss of AC Bus Sources Answer: b.
Question Number 32 The plant is in Mode 3 with reactor startup in progress.An overcooling event has resulted in: Reactor trip SFRCS actuation on low pressure in Steam Generator 1* SFAS actuation on low RCS pressure CCW Pump 2 has failed to start.Which ONE of the following is the next action to be taken?a. Align and start CCW Pump 3 as 2.b. Block and stop HPI Pump 2.c. Block and stop the EDG 2.d. Block and stop MU Pump 2.Answer: c.
Question Number 33 SFAS Channel 1 containment (CTMT) pressure transmitter has failed to 25 psia.What is the expected plant response?a. SFAS Channel 1 trip on high CTMT pressure.b. SFAS Channel 1 trip on high CTMT pressure.SFAS Channel 1 trip on high-high CTMT pressure.c. SFAS Channel 1 trip on high CTMT pressure.RPS Channel 1 trip on high CTMT pressure.d. SFAS Channel 1 alarm on low CTMT pressure.Answer: a.
Question Number 34 The following plant conditions exist: Reactor power is 70%.SG 1 startup level is 157".* SG 2 startup level is 141".The selected SG 1 startup level instrument rapidly fails to mid-scale.
Which ONE of the following describes how the effect on the plant would be different with SASS in auto versus the effect with SASS unable to transfer?a. .In auto, SASS would cause a transfer to the non-selected instrument.
* The same button would stay depressed, however, BOTH would be illuminated.
: b.
* There would be NO difference since in either case OTSG 1 startup level would NOT transfer due to the difference between actual and mid-scale being less than 3% at this power level.c. .In auto, SASS would cause a transfer to the non-selected instrument.
The previously non-selected instrument's pushbutton would become depressed and BOTH buttons would be illuminated.
: d. .There would be NO difference since in either case an automatic transfer to the non-selected instrument would occur.Answer: b.
Question Number 35 A normal plant shutdown is in progress.
In which ONE of the following sequences would the following ICS Hand/Auto stations be placed in HAND/MANUAL by procedural direction?
: 1. Reactor Demand 2. Turbine 3. SG1 Feedwater Demand 4. Rod Control Panel a. 3,4,2,1 b. 1,4,2,3 c. 1,3,4,2 d. 3, 1,2,4 Answer: d.
Question Number 36 The following plant conditions exist:* The plant is in an outage to repair RCP 1-2 seal package.The RCS is drained down to 18" above the cold leg centerline.
* 1-1 Decay Heat Removal loop is in operation.
The following indications are observed: DH Pump 1-1 motor amps becomes erratic.DH Pump 1-1 discharge pressure becomes erratic.* DH Pump 1-1 flow becomes erratic.Which ONE of the following actions is required?a. Stop DH Pump 1-1 and investigate the cause of the above indications.
: b. Stop DH Pump 1-1 and immediately start DH Pump 1-2.c. Immediately decrease decay heat removal flow by throttling closed on DH 1 B.d. After 10 minutes, decrease decay heat removal flow by throttling closed on DH 14B.Answer: a.
Question Number 37 An Equipment Operator (EO) is performing the Emergency Diesel Generator (EDG) 1 184-day test.The EO has had EDG 1 paralleled to Bus C1 for a half hour when he notices the BLUE warning light is energized.
Which ONE of the following is the most likely consequence, assuming no operator action is taken?a. The EDG will trip and restart in the emergency mode.b. The EDG output breaker will trip on generator differential due to transferring to the droop mode.c. The EDG will continue to run in parallel and all normal EDG trips will remain in effect.d. The EDG output breaker will trip on timed overcurrent due to transferring to the isochronous mode.Answer: d.
Question Number 38 The following plant conditions exist: The plant is in Mode 5.* A loss of Y1 has occurred.It is observed that the SFAS data lights in SFAS Channel 3 are red and flashing.
This indicates that a. SFAS Channel 3 is normal and SFAS channel 1 is in a tripped state b. SFAS channels 1 and 3 have tripped, the components have been blocked and are NOT in their SFAS positions c. SFAS channels 1 and 3 have tripped, the components have been blocked and are in their SFAS position d. SFAS Channel 3 is in shutdown bypass and SFAS channel 1 is in a tripped state Answer: d.
Question Number 39 Using Figure 6.2-10, which ONE of the following statements is correct in regards to the containment pressure response?a. Containment spray pumps are actuated by SFAS Level 3 at Point C to limit the containment pressure peak caused by the failure of both trains of containment air coolers at Point B.b. Containment spray pumps are actuated at Point A and have continued to run. The containment pressure peak at Point C is due to containment spray taking a suction on the containment emergency sump at Point B.c. Containment spray pumps and containment air coolers are actuated by an SFAS Level 4 at Point A, and the containment pressure peak at Point C is caused by the containment spray being transferred to the containment emergency sump at Point B.d. Containment spray pumps are manually actuated at Point B, and the second containment pressure peak at Point C is the result of the containment spray pump heat removal reaching equilibrium with the heat generation due to the accident.Answer: b.
Question Number 40 The following plant conditions exist: Reactor startup is in progress after a mid-cycle outage.* Control Rod Groups 1 through 4 have been withdrawn.
A turbine bypass valve has just failed open.Which ONE of the following concerns have the highest priority?a. Prevention of an SFRCS actuation on low steam generator pressure.b. Prevention of an SFRCS actuation on low steam generator level.c. Prevention of criticality due to the positive reactivity addition.d. Prevention of exceeding pressure-temperature limits of the reactor vessel.Answer: c.
Question Number 41 The following plant conditions exist: Reactor startup is in progress.NI 1 and 2 indicate -2 X 104 cps.* NI 3 and 4 indicate -2 X 10-11 amps.NI 2 suddenly fails to 10-1 cps.Which ONE of the following is the correct Tech. Spec. action to apply?a. Open the CRD breakers within one hour.b. Operation may continue, but the inoperable channel must be tripped within one hour.c. Restore the inoperable channel prior to exceeding 10-10 amps.d. Restore the inoperable channel prior to exceeding 5%.Answer: c.
Question Number 42 The following sequence of events has occurred: PORV has failed open due to an instrument failure.The PORV Block Valve, RC10 has failed to close.* The reactor has tripped.Which of the following will be addressed first?a. SG Tube Rupture b. Overcooling
: c. Lack of Heat Transfer d. Loss of Subcooling Margin Answer: d.
Question Number 43 Which ONE of the following combinations represents the correct association of NI channels to power sources?a. NI-1,5, Y1 N1-2,6, Y2 b. N1-4,8, Y4 N1-3,7, Y3 c. NI-2,6, Y1 NI-4,8, Y3 d. NI-2,4, Y2 NI-1,3, Y4 Answer: c.
Question Number 44 The following plant conditions exist: Plant is in Mode 6.Fuel handling operations are in progress.The inner door of the personnel hatch has been closed due to personnel going on break.The Control Room has informed the Fuel Handling Director they will be starting the Containment (CTMT) Purge System on CTMT.The CTMT purge exhaust fan starts. The CTMT purge supply fan inlet damper fails to open and fails to prevent the CTMT purge supply fan from starting.The effects on refueling canal level and spent fuel pool level are, respectively:
: a. increase and decrease b. decrease and increase c. increase and no effect d. no effect and increase Answer: a.
Question Number 45 The following plant conditions exist: The plant is in Mode 6.Refueling operations are NOT in progress.* DH Pump #1 is RUNNING and lined up to the RCS.* DH Pump #2 is O.O.S. and cannot be returned to operable for two days.* Refueling canal level has just been determined to be less than 23 feet.Which ONE of the following actions should be taken next?a. Increase RCS temperature to greater than 140OF and enter Mode 5.b. Open DH 1A and throttle DH flow to 1500 gpm per line.c. Stop all core alterations and positive reactivity changes.d. Increase refueling canal water level to more than 23 feet OR make #2 DH pump operable.Answer: d.
Question Number 46 Which ONE of the following statements describes the purpose of the Diverse Scram System?a. Provides a method to interrupt power to the control rods diverse from the Anticipatory Reactor Trip System by DEENERGIZING relays located in the control rod drive power supply interface cabinet.b. Provides a method to interrupt power to the Reactor Protection System to cause the control rods to drop, thus minimizing the risk from an anticipated transient without scram.c. Provides a method to interrupt power to the Anticipatory Reactor Trip System to cause the control rods to drop, thus minimizing the risk from an anticipated transient without scram.d. Provides a method to interrupt power to the control rods diverse from the Reactor Protection System by ENERGIZING relays located in the control rod drive power supply interface cabinet.Answer: d.
Question Number 47 Following a reactor trip, the following plant conditions exist: Steam Generator (SG) 2 has been isolated by SFRCS and indicates 0 psig.Main Steam Isolation Valve 1 has failed to fully close.* RCS cooldown rate is 60 0 F per hour.Which ONE of the following is the correct operator response?a. Initiate MU/HPI cooling.b. Continue the cooldown with AFW feeding SG1.c. Continue the cooldown with MFW feeding SG1.d. Isolate AFW to both SGs.Answer: b.
Question Number 48 I&C Technicians have informed you that they will be placing the power range Nuclear Instrument (NI) in RPS Channel 3 to TEST OPERATE for the monthly functional.
The NIs on the computer read: N15 N16 N17 N18 99.97 100.09 100.26 100.56 Which ONE of the following statements is correct?a. Placing the reactor demand station into hand will prevent a plant transient.
: b. Placing the steam generator/reactor demand into hand will prevent a plant transient.
: c. There will be no effect on neutron error and no change in control rod position.d. There will be a change in neutron error and control rods may drive in or out.Answer: d.
Question Number 49 Limit and Precaution 2.2.9 of DB-OP-06021, Spent Fuel Pool Operating Procedure, states that SFP pumps are NOT to be operated when cooling the SFP with a decay heat removal pump.The reason for this requirement is to prevent a. cavitation of the running DHR pump b. cavitation of the running SFP pump c. pumping the RCS to the SFP d. pumping the SFP to the BWST Answer: b.
Question Number 50 The following plant conditions exist:#1 WGDT selected for "H 2 SURGE TANK"#2 WGDT selected to "OFF"#3 WGDT selected for "NITROGEN"#1 WG compressor is DNO'd#2 WG compressor for "Both"* WGST pressure = 8.1 psig Which ONE of the following events would occur if the cover gas header subsequently reaches 5 psig?a. #2 WG compressor will align itself to the cover gas header exclusively.
: b. #2 WG compressor will continue to pump down the surge tank unless the cover gas header reaches 7.0 psig, then will align to the cover gas header exclusively.
: c. #2 WG compressor will continue to pump down the surge tank unless cover gas header reaches 7.0 psig, then the compressor will align to BOTH the cover gas header and the WGST.d. #2 WG compressor will stay aligned exclusively to the WGST regardless of cover gas pressure as long as WGST pressure is greater than 7.0 psig.Answer: c.
Question Number 51 The purpose of the Anticipatory Reactor Trip System is to a. provides a backup to the Reactor Protection System high RCS pressure trip b. ensures the main turbine trips when reactor power is greater than 40%c. limits RCS pressure transients that challenge the PORV due to secondary events d. prevent RCS pressure transient that could actuate the Diverse Scram System Answer: c.
Question Number 52 Which ONE of the following conditions is an indication of an intermediate range channel being undercompensated?
: a. After a reactor trip, the intermediate range channel shows a more rapid decrease in reactor power level.b. On reactor startup, the startup rate of the affected channel is higher.c. After a reactor trip, the source range channels energize prior to 5 x 10-10 amps on the intermediate range channel.d. On reactor startup, the intermediate range channel comes on scale prior to the source range getting to 1 X 104 counts.Answer: d.
Question Number 53 A small break LOCA has occurred resulting in a loss of Subcooling Margin (SCM).The following plant conditions currently exist:* RCS pressure is 800 psig.* RCS T-cold is 545 0 F and decreasing.
* RCS average incore temperature is 542 0 F and decreasing.
Pressurizer level is 45" and increasing.
* Steam generator levels are being maintained per Specific Rule 3.Which ONE of the following statements is correct, given the above conditions?
: a. Maintain maximum HPI flow until pressurizer level is restored to 80-120 inches.b. Immediately start a 100F/hr. cooldown to Mode 5 to allow for repair of the break and an engineering evaluation.
: c. Throttle HPI flow to maintain RCS pressure near minimum SCM and cooldown at less that 5 0&deg;F/hr.d. Maintain maximum HPI flow except to prevent exceeding pressure-temperature limits.Answer: c.
Question Number 54 The following sequence of events occurred: Reactor trip on low RCS pressure.* RCPs were tripped due to a loss of subcooling margin.The Control Room SRO has asked you to check for inadequate core cooling. You observe that the subcooling margin meters have a red light lit on them and they read zero.Which ONE of the following statements is correct?a. Select the Incore thermocouples as the input to the subcooling margin meters due to their faster instrument response time for present RCS conditions.
: b. Select the T-hot as the input to the subcooling margin meters due to their faster instrument response time for present RCS conditions.
: c. Inform the Control Room SRO that inadequate core cooling exists for the present RCS conditions.
: d. Use T-hot and RCS pressure to determine the status of the subcooling margin for the present RCS conditions.
Answer: a.
i.-C -kl-k- I\e I rfz Question Number 56 The following plant conditions exist: A reactor startup is in progress.Current rod index is 285.The upper rod index limit is 285.Initial count rate was 4X10 1 cps on source range NI 1 and 2.* Current count rate is stable at 6xl 0 2 Cps on source range NI 1 and 2.Which ONE of the following is the next action to be taken?a. Add demin. water to lower rod index.b. Insert all regulating and all safety rods, except Group 1.c. Continue the reactor startup to 10-8 amps.d. Insert all regulating rods; safety rods can remain withdrawn.
Answer: b.
Question Number 57 The following plant conditions exist:* LPI Pump 2 is tagged out and disassembled for a motor bearing replacement.
* A small break LOCA occurred approximately two hours ago.An SFAS Level 2 actuation occurred and all safety systems responded as expected.The BWST is at 7 ft.* RCS pressure is 925 psig, temperature is 400 0 F.The Control Room SRO has just directed the RO to stop HPI Pump 2 and piggyback HPI Pump 1 with LPI Pump 1. Which of the following is the most significant reason for this action?a. HPI Pump 2 is stopped to prevent contamination of the BWST when suction is on the emergency sump.b. LPI Pump 1 lacks the flow capacity to support piggyback of both HPI pumps when drawing from the emergency sump.c. Prevent exceeding Reactor Vessel P-T limits due to running both HPI pumps in piggyback mode on the emergency sump.d. Prevent a loss of injection flow due to current RCS pressure when transferring LPI Pump 1 suction to the emergency sump.Answer: d.
Question Number 58 While operating at 50% power, the following symptoms are observed: High condenser pressure alarm Mechanical hogger auto starts LP turbine exhaust hood spray actuated* Condenser pressure is 7.9 in. HgA and constant (Assume all systems operate as designed.)
Which ONE of the following is the appropriate action?a. Trip MFPTs and ensure ICS runs the plant back to approximately 15% power.b. Commence a rapid shutdown to less than 28% power and then manually trip the turbine.c. Carry out the actions of DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture.d. Commence immediate plant shutdown to establish Mode 3 conditions.
Answer: c.
Question Number 59 The following plant conditions exist: A loss of offsite power has occurred.* All expected automatic actions have occurred.Which ONE of the following confirms natural circulation flow has been established?
: a. Thot and SG Tsat are coupled and tracking.b. There is a 70 0 F difference between Thot and Tcold.c. Incore temperatures and Thot are coupled and stable.d. Thot, Tcold, and incore temperatures do not change when SG pressure is changed.Answer: c.
Question Number 60 Which ONE of the following is the basis for the Control Room Alarm 12-2-A(B), SG 1(2) TO AFPT 2(1) MN STM PRESS LO?a. Prevent excess blowdown of a steam generator that will limit the amount of positive reactivity added to the core.b. Prevent robbing the auxiliary feed pump turbines of steam due to a rupture in their steam supply lines.c. Prevent backfeeding a rupture in one steam generator from the other steam generator to limit the amount of blowdown in the unaffected steam generator.
: d. Prevent exceeding environmental qualification by alerting the control room of an unisolable steam leak in fan alley.Answer: d.
Question Number 61 Which ONE of the following parameters is a Limiting Safety System setting violation that would require placing the reactor in HOT STANDBY within one hour?a. Reactor power at 104.9% with four pumps operating.
: b. RCS hot leg temperature at 61 0OF.c. Reactor coolant pressure at 2400 psig.d. Reactor power at 70.6% with three pumps operating.
Answer: c.
Question Number 62 The following plant conditions exist: Pressurizer level is constant.Makeup tank level is decreasing at 2 inches per minute.RE 1003A, Vacuum System Discharge RCM, is in alarm high.* RE 600, Main Steam Line 2 RE, is in alarm high.Which ONE of the following will provide the appropriate procedural guidance?a. DB-OP-02531, Steam Generator Tube Leak b. DB-OP-02513, Pressurizer System Abnormal Operations
: c. DB-OP-02522, Small RCS Leaks d. DB-OP-02512, Loss of RCS Makeup Answer: a.
Question Number 63 The following plant conditions exist: EDG 1 was out of service for turbo charger replacement.
A tornado has destroyed all three off-site lines.* D1 has experienced a lockout.Which ONE of the following loads must be deenergized from the Control Room within 30 minutes?a. RCP lift oil pumps b. T-G turning gear oil pump c. Atmospheric vent valves d. Emergency seal oil pump Answer: a.
Question Number 64 During a LOCA, containment temperature has been determined to be greater than 1 50 0 F.Which ONE of the following actions is required?a. Shift containment air cooling fans to fast speed.b. Initiate containment spray.c. Manually maintain PZR level greater than 80 inches.d. Start a second CCW pump.Answer: c.
Question Number 65 The plant is in Mode 3. An equipment operator informs you that the operating steam jet air ejector first stage discharge check valve is stuck closed.Main condenser pressure will a. remain constant b. decrease to < 0.5" HgA c. rise to 4.0" HgA when steam hogger starts d. rise to 4.5" HgA when the mechanical hogger will start Answer: d.
Question Number 66 The plant is in Mode 1 when the following alarms come in:* 11-6-C, SW PMP 3 STRNR AP HI 11-1-B, CCW HX 1 OUTLET TEMP HI P945, SW HDR 1 PRESS* T080, CC HX 1 OUT TEMP Which ONE of the following will provide appropriate procedural guidance actions to mitigate the event?a. DB-OP-0251 1, Loss of Service Water Pumps/System, for a loss of SW Loop 1.b. DB-OP-0251 1, Loss of Service Water Pumps/System, for loss of SW Loop 2.c. DB-OP-02523, Component Cooling Water System Malfunctions, for operating CCW pump failure.d. DB-OP-02523, Component Cooling Water System Malfunctions, for a loss of CCW to all RCPs.Answer: a.
Question Number 67 The following plant conditions exist:* Steam Generator 1 has a tube rupture.* Four RCPs are running.TBVs are being used to steam both steam generators.
* Steam Generator 1's level is 215" and increasing.
Which ONE of the following is the next action to be taken?a. Increase the steaming rate of Steam Generator 1.b. Isolate Steam Generator 1 and continue to cooldown Steam Generator 2 using the TBVs.c. Trip all but one RCP to reduce the leak flow rate.d. Isolate Steam Generator 1 and continue to cooldown Steam Generator 2 using the AVVs.Answer: a.
Question Number 68 A complete loss of AC bus power sources has occurred.
Which ONE of the following statements describes expected plant status after 2 hours of these conditions?
: a. Natural circulation, automatic control of AVVs for heat removal, maintaining hot standby.b. Natural circulation, manual control of AVVs for heat removal, cooling down to cold shutdown.c. Natural circulation, manual control of AVVs for heat removal, maintaining hot shutdown.d. Natural circulation, automatic control of AVVs for heat removal, cooling down to cold shutdown.Answer: b.
Question Number 69 The following plant conditions exist: CTMT temperature is 65 0 F.* SW1 356, CAC 1 SW outlet temperature control valve is set at 70 0 F.An operator starts CAC 1, and observes the SW1356 went from close to open.What is the status of CAC 1?a. OFF with a white overload light lit.b. Running in SLOW.c. Running in FAST.d. All lights on the CAC 1 controller are OUT.Answer: b.
Question Number 70 Which of the following combinations are all substations with DIRECT tie-in to Davis-Besse's 345 KV switchyard?
: 1. Acme 2. Bayshore 3. Eastlake 4. Lemoyne 5. Ohio Edison -Beaver substation
: a. 1,3,4 b. 2,4,5 c. 1,2,4 d. 3,4,5 Answer: b.
Question Number 71 Which ONE of the following combinations represents the regulatory exposure limits of 1 OCFR20?a. -5.0 R/year TEDE-15.0 R/year to the skin-15.0 R/year to the lens of the eye b. -5.0 Rlyear TEDE-15.0 R/year to the lens of the eye-50.0 R/year to extremities
: c. -3.0 R/year TEDE-15.0 R/year to the skin-50.0 R/year to extremities
: d. -1.0 R/year TEDE-15.0 R/year to the extremities
-50.0 R/year to the skin Answer: b.
Question Number 72 The following plant conditions exist:* The reactor has tripped due to a loss of both MFPs.Both auxiliary feedwater pump turbines have tripped.* Both steam generator levels read 12" on the startup range.Which ONE of the following is the preferred method to feed a steam generator?
: a. Motor driven feedwater pump via the Auxiliary Feedwater System.b. Motor driven feedwater pump via the Main Feedwater System.c. Startup feedwater pump via the Auxiliary Feedwater System.d. Main feedwater pump via the Main Feedwater System.Answer: a.
Question Number 73 The purpose of the service water non-seismic line rupture section of DB-OP-0251 1, Loss of Service Water Pumps/System is to prevent a loss of _a. cooling tower makeup b. ultimate heat sink inventory c. auxiliary feedwater alternate suction source d. turbine plant cooling water cooling Answer: b.
Question Number 74 Which ONE of the following describes the MDFP lineup above 450 MWe?a. MDFP to Main Feedwater Isolation Valve, FW 6396, is fully open to supply maximum flow to a depressurized OTSG.b. MDFP suction is from the CST with its discharge flowpath to the AFW headers.c. MDFP discharge valves to the AFW headers are throttled to 40% open.d. MDFP to Main Feedwater Isolation Valve, FW 6396, is throttled to allow -1000 gpm flow to a depressurized OTSG.Answer: b.
Question Number 75 From the following list, which ONE of the following sets of loads are ALL powered from the DCMCC2 250 VDC bus?1. Two emergency lighting panels 2. RCP 1-1 and 2-2 lift pumps 3. RCP 1-2 and 2-1 lift pumps 4. MFPT 1-2 EBOP 5. MFPT 1-1 EBOP 6. ESOP 7. Inverter YVB 8. Inverter YVA a. 1,2,5,8 b. 3,4,6,7 c. 2,3,7,8 d. 1,4,5,6 Answer: b.
Question Number 76 The following plant conditions exist: Plant is in Mode 5.* Containment (CTMT) Purge System is in operation on CTMT.RE 5052C, CTMT Purge System RCM, has alarmed high.Which ONE of the following is the next action to be taken?a. Stop the CTMT purge exhaust and supply fans.b. Close the CTMT isolation dampers for the CTMT Purge System.c. Start one of the Emergency Ventilation System (EVS) fans.d. Open the CTMT Purge System to EVS damper.Answer: c.
Question Number 77 The following plant conditions exist: The reactor has tripped due to loss of both main feedwater pumps.Auxiliary Feedwater Pump 1 has tripped on overspeed.
Auxiliary Feedwater Pump 2's steam admission valve has failed to open.Loop 1 T-hot is 600 0 F.* Loop 2 T-hot is 602 0 F.Which ONE of the following is the procedural route to be taken upon exiting Section 4 of DB-OP-02000?
: a. Section 6, Lack of Heat Transfer b. Section 9, ICC c. Attachment 1, Guidelines for Restoring Feedwater d. Attachment 4, Initiate MU/HPI Cooling Answer: d.
Question Number 78 During a LOCA in which inadequate core cooling exists, DB-OP-02000 has you raise SG level to 124" and lower SG pressure to achieve secondary Tsat 900 to 1 10OF less than Tsat of the existing RCS pressure.Which ONE of the following is the reason for these actions?a. Promotes boiler condenser cooling to cool the primary system.b. Maintains a normal primary to secondary differential pressure to minimize the possibility of an SG tube failure.C. Minimizes the tube to shell differential temperature to prevent failure of the SG and increasing the LOCA size.d. Lowers SG temperature which prevents the SG from becoming a heat source and compounding the accident.Answer: a.
Question Number 79 If BOTH LPFW Heaters 1-1 and 2-1 are bypassed, the maximum allowable power is 50%. This maximum limit is based upon insufficient to support higher power levels.a. preheating of the condensate
: b. extraction steam removed from the turbine c. flow capacity through the Condensate System d. ion removal in the polishers Answer: c.
Question Number 80 The following sequence of events have occurred: Large break LOCA Loss of off-site power has occurred C--1 bus locks out when AC 101 closes* EDG 1 trips on overspeed Which ONE of the following actions will have the highest priority?a. Establish containment integrity.
: b. Restore off-site power.c. Have an equipment operator investigate the C1 bus lockout.d. Initiate AFW and isolate steam generators.
Answer: a.
Question Number 81 Immediately following a reactor trip, the following conditions exist: All CRD trip breakers open.Control Rod Group 3 has failed to insert.* Intermediate power range is indicating 5 X 10-4 amps and constant.Which ONE of the following is the next action to be taken?a. Enter DB-OP-02510, Loss of Reactor Coolant System Boron, and initiate immediate boration.b. Enter DB-OP-02516, CRD Malfunctions, and attempt to insert Control Rod Group 3.c. Enter DB-OP-02000, RPS, SFAS, SFRCS, or SG Tube Rupture, and commence emergency boration.d. Enter DB-OP-02000, RPS, SFAS, SFRCS, or SG Tube Rupture, and momentarily deenergize E2 and F2.Answer: c.
Question Number 82 With the plant operating at 100% power, a loss of D1 P and DAP has occurred.The reason the operator is directed to commence a rapid power reduction for these conditions is that a. the resultant Condensate/Feed System flowrate cannot support the current power level b. the loss of power has disabled the main turbine automatic and Control Room demanded trips c. the loss of power prevents the Integrated Control System from automatically performing the plant runback d. seal return flow from the reactor coolant pumps has been isolate concurrent with a loss of component cooling water Answer: a.
Question Number 83 Which ONE of the following describes the basis for tripping all operating reactor coolant pumps on the loss of SCM?a. To reduce the amount of coolant lost through a break.b. To prevent damage to the reactor coolant pump motors.c. To prevent cavitation damage to the reactor coolant pumps.d. To reduce the amount of heat being added to the RCS.Answer: a.
Question Number 84 The following plant conditions exist: Reactor demand hand/auto station meter indicates 90%.* Both feedwater demand hand/auto station meters indicate 81%.An instrument failure reduced feedwater flow to a flowrate require for 82% RTP.Which ONE of the following will occur as a result of the instrument failure?a. Reactor demand hand/auto station meter will decrease to 74%.b. Feedwater demand hand/auto station meters will decrease to 75%.c. Reactor demand hand/auto station meter will increase to 91%.d. Feedwater demand hand/auto station meters will increase to 82%.Answer: a.
Question Number 85 Which ONE of the following process radiation monitors causes an automatic plant system response in addition to its high radiation alarm?a. Failed fuel detector -RE 1998 b. Control Room emergency ventilation
-RE 5327 c. Unit vent -RE 4598 AA d. Service water discharge header -RE 8432 Answer: c.
Question Number 86 The plant has just entered Mode 5 for a.scheduled refueling outage. The following RCS conditions exist: Tave= 155 0 F RCS pressure = 60 psig* Pzr level = 85" The RCS cooldown and depressurization continues using DHR Train 1, when the following annunciators actuate: 1-3-D, BUS C1 LOCKOUT* 1-3-H, BUS D1 LOCKOUT* 1-4-D, BUS C1 VOLTAGE 1-4-E, BUS A LOCKOUT 1-4-G, BUS B LOCKOUT* 1-4-H, BUS D1 VOLTAGE DB-OP-02527, Loss of DHR System, has been implemented.
Which ONE of the following represents final plant conditions?
: a. Mode 4, Forced circulation
: b. Mode 4, Natural circulation
: c. Mode 5, gravity draining the BWST into the RCS d. Mode 5, Forced circulation Answer: b.
Question Number 87 The following plant conditions exist: A release of Clean Waste Monitor Tank (CWMT) 1 is in progress.Five minutes after starting the release, RE-1770A, Clean Waste System Outlet RCM, shows an alert and high alarm.Which ONE of the following is the expected response of the Clean Waste System?a. The operating CWMT transfer pump trips and WC-1771, Clean Liquid Radwaste Discharge Flow Control Valve, closes.b. The operating CWMT transfer pump trips and WC-1704, CWMT 1 Outlet Flow Control Valve, closes.c. The operating CWMT transfer pump continues to run and WC-1771, Clean Liquid Radwaste Discharge Flow Control Valve, closes.d. The operating CWMT transfer pump continues to run and WC-1 704, CWMT 1 Outlet Flow Control Valve, closes.Answer: c.
Question Number 88 The following events have occurred: Alarm Letdown Rad High (2-1-A) has actuated.RE8409, Penetration Room 208, has alarmed and radiation levels are increasing.
RE8410, Corridor 209, has alarmed and radiation levels are increasing.
* RE841 1, Corridor 209, has alarmed and levels are increasing.
Which ONE of the following is the next action to be taken?a. Call Chemistry to sample the station vent.b. Evacuate the Auxiliary Building.c. Evacuate Mechanical Penetration Room 1.d. Reduce reactor power to reduce radiation levels.Answer: b.
Question Number 89 The reactor is operating at full power when actual feedwater temperature decreases from 454 0 F to 430 0 F.Which ONE of the following is the response expected from this event?a. Both feedwater flow and reactor power will decrease.b. Both feedwater flow and reactor power will increase.c. Feedwater flow will increase and reactor power will decrease.d. Feedwater flow will decrease and reactor power will increase.Answer: d.
Question Number 90 Which ONE of the following is the power supply for the backup service water pump?a. C1 b. C2 c. D1 d. D2 Answer: b.
Question Number 91 The following plant conditions exist: A gaseous waste batch release (i.e., WGDT) is being performed, and the station vent monitors subsequently alarm.If these alarms do NOT clear after batch release termination, it must be determined if the release is in excess of the Off-Site Dose Calculation Manual (ODCM).Which ONE of the following procedures requires this determination?
: a. RA-EP-01500, Emergency Classification
: b. RA-EP-02861, Radiological Incidents c. DB-OP-06412, Process and Area Radiation Monitor d. HS-EP-02240, Offsite Dose Assessment Answer: b.
Question Number 92 The following plant conditions exist:* Loss of off-site power.* Plant has been stabilized.
The Shift Supervisor has decided to restore instrument air.Which ONE of the following is the preferred air compressor to restore?a. SAC 1 b. SAC 2 c. EIAC d. Order a diesel air compressor to be installed.
Answer:c.
Question Number 93 Which ONE of the following describes the effect that loss of NNI-X DC will have on automatic pressurizer pressure control?a. Both the PORV and the spray valve will fail open.b. Both the PORV and the spray valve will fail closed.c. The PORV will fail open and the spray valve will fail closed.d. The PORV will fail closed and the spray valve will fail open.Answer: b.
Question Number 94 Which of the following power supplies are the sources of power for the AFP 1 discharge to SG1 (AF3870)and the AFP 2 discharge to SG2 (AF3872)?a. El1E, F12A b. YlA, Y2A c. D1PA, F12B d. EllC,D2P Answer: c.
Question Number 95 Under which ONE of the following circumstances will the emergency instrument air compressor supply station air loads?a. When a spool piece between the emergency instrument air compressor and the station air header has been installed.
: b. When started by local operator action, since the emergency instrument air compressor is normally lined up to station air.c. When the emergency instrument air compressor is lined up to station air and emergency instrument air receiver pressure is greater than 95 psig.d. When instrument air receiver pressure is less than 95 psig the instrument air and station air are operated as a common system.Answer: c.
Question Number 96 The plant is at 100% power when Control Rod 5-7, at core location E5, drops fully into the core. (See figure 2 of the COLR)Which of the following is used to monitor the effects of the dropped control rod?1. Axial Power Imbalance Monitoring System 2. Quadrant Power Tilt Monitoring System 3. Rod Insertion Limits Monitoring System 4. Incore Thermocouple Monitoring System 5. Power Range Nls a. 1,2,and3 b. 3,4,and5 c. 1,3,and4 d. 2,3,and5 Answer: d.
Question Number 97 The plant has been operating at 100% RTP for four weeks when the following conditions are observed: 1. Annunciators:
* 6-5-B, SEAL CCW FLOW LO* 6-5-C, SEAL INJ FLOW LO* 6-6-C, SEAL INJ TOTAL FLOW* 11-4-B, CCW PMP 1 FLOW LO 2. All four seals return temperatures are rising.Which ONE of the following is an IMMEDIATE operator action for the observed condition?
: a. TRIP all four RCPs and initiate AFW flow and isolation of BOTH steam generators.
: b. TRIP the reactor and TRIP all RCPs and go to DB-OP-02000.
: c. START the second makeup pump and restore flow through MU 19, RCP Seal Injection Flow Control Valve.d. Monitor seal return temperatures while attempting to restore CCW flows to all for RCPs.Answer: b.
Question Number 98 The following plant conditions exist: A loss of all feedwater is in progress.* Highest Thot is 577 0 F.If the PORV should open while attempting to restore feedwater, the PORV block should not be closed a. because if the PORV block valve fails closed, the feed and bleed flowpath will be lost b. unless the PORV has failed open c. because if the PORV block valve fails closed, the RCS will not have overpressure protection for all situations
: d. unless RCS pressure reaches the SCM limit.Answer: a.
Question Number 99 A fire suppression area alarm is received followed by the AUTO start of one fire pump. Which ONE of the following actions is required to be performed FIRST as a result of these conditions?
: a. If any other fire alarm is received, then activate the Fire Brigade.b. An operator must be dispatched to investigate, then acknowledge the alarm.c. Inform the Shift Manager and Shift Supervisor, then acknowledge the alarm.d. The Fire Brigade must be activated immediately.
Answer: d.
Question Number 100 The reason for the operator manually tripping RE 8446 and RE 8447, Fuel Handling HVAC System REs, during a fuel handling accident in the SFP area is to _a. filter out noble gases and control radiation release via the station vent b. filter out particulates/iodine and control the radiation release via the station vent c. provide an alarm to notify workers to evacuate and automatically start the CTRM EVS d. filter out noble gases/iodine and pressurize the fuel handling area Answer: b.
Answer Key 1.2.3.4.5.6.7.8.9.10.11.12.13.14.15.16.17.18.19.20.21.22.23.24.25.26.27.28.29.
Answer Key 30. d.31. b.32. c.33. a.34. b.35. d.36. a.37. d.38. d.39. b.40. c.41. c.42. d.43. c.44. a.45. d.46. d.47. b.48. d.49. b.50. c.51.52.53.54.55.56.57.58.59.C.d.C.a.C.b.d.C.C.
Answer Key 60.61.62.63.64.65.66.67.68.69.70.71.72.73.74.75.76.77.78.79.80.81.82.83.84.85.86.87.88.89.d.C.a.a.C.d.a.a.b.b.b.b.a.b.b.b.C.d.a.C.a.C.a.a.a.C.b.C.b.d.
Answer Key 90.91.92.93.94.95.96.97.98.99.100.b.b.C.b.C.C.d.b.a.d.b.
COLR Page 1 I of 25 Revision 0 Figure 2 Control Rod Core Locations and Group Assignments Davis-Besse
: 1. Cycle 12 N Figure is referred to by Technical j Specification 3.1.3.7.4 N X 8 Y B3 Group Number I 5 6 7 8 9 l 10 l 11 12 13 Group No. of Rods Function 1 4 Safety 2 8 Safety 3 4 Safety 4 9 Safety 5 12 Control 6 8 Control 7 8 Control 8 8 APSRs Total 61 C-Tl 68 DB-PF-06703 REVSION 03 CC 6.9 A POWER RANGE NUCLEAR INSTRUMIENTAIION/HEAT BALANCE POWER CAIBRATION RELAMONSHIP EXPANDED VIEW OF UPPER REGION HEAT HAUANCR POWER *NFPP 10(90 XO t0 z'7 57-n HEA _AAC .W~ .., ..RECALIBRATE AS DIRECTED BY THE SHIFT SUPERVISOR UKNACCEPTABLE
-- REGION.- -.i~ .-.._ ,-_.- ....-.Or...o, ... .. .........
> .,... tE4CCETABE
-60 so 40 40 50 60 70 80 90 HEAT BALANCE POWER */%FP_ -Defines Desired Region i----NI Operability Limit Line *Ihis is 0.5% below calibration required limit line.
l PAVIS-BESSE NUCLEAR POWER STATION LONG TERM CONTAINNENT PRESSURE RESPONSE FOR THE 14.14 FT.Z OBA BREAK WITH ECCS QUENCHING (I.C-5)FIGURE 6.2-10 RFV1S1LWN U
Page 1 of 54 Davis-Besse Nuclear Power Station PLANT PROCEDURE DB-NE-0620 1 REACTOR OPERATORS CURVE BOOK REVISION 04/TOTAL REWRITE Prepared by: Sponsor: \- V'., ;-f Supervisor
-Nuclear Engineering Approved by: a-nEn Manager -Design sis Engineering Effective Date: 5 /1 -5 Il 9 s5 //2 Date Date Date Procedure Classification:
X Safety Related__ Quality Related__ Non-Quality Related III I.........-.., -W -, i 4 .* t, * '-
2 DB-NE-06201 Revision 04 REACTOR OPERATORS CURVE BOOK LIST OF EFFECTTVE PAGES Page Change No.2 1 3 5 6 7 8 9 I 10 I11 12 13 14 15 16 17 1 8 19 20 21 2 2 _ _ _ _ _ _ _ _ _Page Change No.23 24+25 26 27 Page Change No.45 46 47 48 49 50 51 52 53 54 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 3 DB-NE-06201 Revision 04 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS Page 1.0 PURPOSE ........................................................
7 2.0 LIMITS AND PRECAUTIONS
.........................
...............................
7
 
==3.0 REFERENCES==
 
.......................................................
7 FIGURE TITLE I Fuel Excess Reactivity Worth, "Power" Reference Condition, Page I of 2, 380 EFPD .8 Fuel Excess Reactivity Worth, "Power" Reference Condition, Page 2 of 2, 2320 EFPD .9 2 Fuel Excess Reactivity Worth, "Critical" Reference Condition, Page I of 2, <380 EFPD .10 Fuel Excess Reactivity Worth, "Critical" Reference Condition, Page 2 of 2, 320 EFPD .11 3 Integral Worth of Soluble Boron, 0 EFPD, Page I of 2, 1400 ppmB ................
........................................
12 Integral Worth of Soluble Boron, 0 EFPD, Page 2 of 2, 1200 ppmB .........................................................
13 4 Integral Boron Worth Correction Factor, Page 1 of 2, 380 EFPD ..................
14 Integral Boron Worth Correction Factor, Page 2 of 2, 320 EFPD ..................
15 SA Differential Reactivity Worth of Soluble Boron,"Critical" Reference Condition, Page 1 of 2, APSRs In .16 Differential Reactivity Worth of Soluble Boron,"Critical" Reference Condition, Page 2 of 2, APSRs Out .17 SB Differential Reactivity Worth of Soluble Boron,"Power" Reference Condition, Page I of 2, APSRs In I 8 Differential Reactivity Worth of Soluble Boron,"Power" Reference Condition, Page 2 of 2, APSRs Out .19 4 DB-NE-06201 Revision 04 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS (Continued)
FIGURE TITLE 6A Minimum Boron Concentration to Assure 1% AK/K Shutdown Margin, NO Known Stuck Rod, Page 1 of 2, <380 EFPD ..............................................
20 Minimum Boron Concentration to Assure 1% AK/K Shutdown Margin, NO Known Stuck Rod, Page 2 of 2, 2320 EFPD ..............................................
21 6B Minimum Boron Concentration to Assure 1% AK/K Shutdown Margin, ONE Known Stuck Rod, Page I of 2, <380 EFPD .22 Minimum Boron Concentration to Assure 1% AK/K Shutdown Margin, ONE Known Stuck Rod, Page 2 of 2, 2320 EFPD .23 7 RCS Water Volume Versus Pressurizer Level .24 8 Integral Control Rod Worth Groups 5-7, "Power" Reference Condition, Page I of 4, GRPs 5-7, APSRs In .......................................................
25 Integral Control Rod Worth Groups 5-7, "Power" Reference Condition, Page 2 of 4, GRPs 5-7, APSRs Out .......................................................
26 Integral Control Rod Worth Group 7, "Power" Reference Condition, Page 3 of 4, expanded Group 7, APSRs In .......................................................
27 Integral Control Rod Worth Group 7, "Power" Reference Condition, Page 4 of 4, expanded Group 7, APSRs Out .....................................................
28 9A Integral Control Rod Worth Groups 5-7, "Critical" Reference Condition, NO Xenon, Page I of 4, GRPs 5-7, APSRs In ..................................................
29 Integral Control Rod Worth Groups 5-7, "Critical" Reference Condition, NO Xenon, Page 2 of 4, GRPs 5-7, APSRs Out ................................................
30 Integral Control Rod Worth Group 7, "Critical" Reference Condition, NO Xenon, Page 3 of 4, expanded Group 7, APSRs In ....................................
31 Integral Control Rod Worth Group 7, "Critical" Reference Condition, NO Xenon, Page 4 of 4, expanded Group 7, APSRs Out ..................................
32 5 DB-NE-06201 Revision 04 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS (Continued)
FIGURE TITLE 9B Integral Control Rod Worth Groups 5-7, "Critical" Reference Condition, PEAK Xenon, Page I of 4, GRPs 5-7, APSRs In ..............................................
33 Integral Control Rod Worth Groups 5-7, "Critical" Reference Condition, PEAK Xenon, Page 2 of 4, GRPs 5-7, APSRs Out ...........................................
34 Integral Control Rod Worth Group 7, "Critical" Reference Condition, PEAK Xenon, Page 3 of 4, expanded Group 7, APSRs In ................................
35 Integral Control Rod Worth Group 7, "Critical" Reference Condition, PEAK Xenon, Page 4 of 4, expanded Group 7, APSRs Out .............................
36 10 Adjusted Reactivity Worth of GRPs 1-7 (R), Page I of 2, 360 EFPD ...........
37 Adjusted Reactivity Worth of GRPs 1-7 (R), Page 2 of 2, 2340 EFPD ...........
38 11 A APSR Reactivity Worth, "Critical" Reference Condition
.................................
39 11 B APSR Reactivity Worth: "Power" Reference Condition
...................................
40 12 Temperature Coefficient of Reactivity versus Boron Concentration at 532 0 F, Page I of 2, APSRs In ......................
; .......................
41 Temperature Coefficient of Reactivity versus Boron Concentration at 532 0 F, Page 2 of 2, APSRs Out .......................................................
42 13 Hot Standby Critical Boron Concentration, Page I of 2, 380 EFPD ..............
43 Hot Standby Critical Boron Concentration, Page 2 of 2, 2320 EFPD ..............
44 14 Power Doppler Reactivity Deficit, Page I of 2, APSRs In ...............
................
45 Power Doppler Reactivity Deficit, Page 2 of 2, APSRs Out .............................
46 15 Minimum Boron Concentration to Ensure 1% AK/K Shutdown Value, Page 1 of 2, 380 EFPD .47 Minimum Boron Concentration to Ensure 1% AK/K Shutdown Value, Page 2 of 2, 2320 EFPD .48 16 Deleted 6 DB-NE-06201 Revision 04 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS (Continued)
FIGURE TITLE 17A Axial Power Imbalance Alarm and RPS Allowable Values, 4 Pump Operation
.........................................................
49 1 7B Axial Power Imbalance Alarm and RPS Allowable Values, 3 Pump Operation
.........................................................
50 18A Error Adjusted Rod Insertion Limits, 4 Pump Operation
...............
..................
51 1 8B Error Adjusted Rod Insertion Limits, 3 Pump Operation
...............
..................
52 19 APSR Position Limits .........................................................
53 TABLE Miscellaneous Physics Parameters
............-----------
-------- -5_I ................................................................................................................., _. ............................................
7 DB-NE-0620 1 Revision 04 r-------------------------------------
NOTE 1.0 I This procedure will not follow the normal procedure because the normal format is not applicable.
l 1.0 PURPOSE This procedure provides curves that are: 1) guidelines in operating the reactor and, 2)necessary to execute various procedures (e.g., DB-OP-0600 1, "Boron Concentration Control", and DB-NE-06202, "Reactivity Balance Calculation").
2.0 LIMITS AND PRECAUTIONS 2.1 Some figures contain curves for different times in core life (i.e., different EFPDs).Values at other times in core life should be determined by linear interpolation between the two curves that bound the desired time in core life. An approximate interpolated value may be determined by reading the value directly from the figure.A formal calculation is not required.2.2 Do not attempt to interpolate between two curves that are at different temperatures or between the 'Power" and "Critical" reference conditions.
These types of interpolations may not be linear.2.3 Some curves have a step change near the end of core life due to APSR removal.After APSRs are removed, use the curve segment after the step change.2.4 Due to extended cycle lengths, the data for some figures is split into two curves on separate pages.2.5 Figures that are labeled "APSRs In" have the data for "APSRs Out" on a separate page. Use the curves labeled "APSRs In" until the APSRs are removed towards the end of core life. After the APSRs are removed, use the curves labeled "APSRs Out."
 
==3.0 REFERENCES==
 
3.1 Manuals 3.1.1 Automated Testing and Operations Manual (ATOM) for the present cycle.
SOURCE C-NRE-062.02.9 Rev 0 DAM May 8,1998 HME 11:53:49 PREPARERiLtL nDATg _/e/ 8 REVMWR: S::, -DATh--E: -lb Cycle 12 Fuel Excess Reactivity Worth -"Power" Reference Condition 14.5 14.0 13.5 13.0 12.5--CZ)a1 12.0 11.5 11.0 10.5--oo 10.0 9.5 9.0 8.5 8.0 7.5-7.0 IS Pt I'l our (6.5-V 0 20 40 60 80 100 120 I 140 160 180 200 220 240 260 280 300 340 360 320 3 380 0 EFPD SOURCFh C-NRE-062.2O96 Rev 0 DATE., May S.,1998 TRMh 11:53:49 REVEEWE:-
_DATMI NEW Cycle 12 Fuel Excess Reactivity Worth -"Power" Reference Condition 10.0 i j -, I ..I I I I I .-9.5 ......4 9.0- -----8.5 8.0 44 7.5~7.0 6.5 6.0 4 5.5 '*~5.0 o 4.5 4.0 3.5 3.0 2.5 2.0 1.5 Z :;i 1.0 S.. -2. 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 70 EFPD SOURCE C-NRE-062.M2M6 Rev 0 DATED May 8,1998 TIME 11:56:05 PREPARERt I DAE. 5-8 -8 REVIEWER:
g DATE- ._1___l_Cycle 12 Fuel Excess Reactivity Worth -"Critical" Reference Condition 18.0 17.5 17.0 16.5 16.0 14)A>cdn 15.5 15.0 14.5 14.0 13.5 0 13.0 12.5 12.0 11.5 11.0 10.5 10.0 9.5 1A It-_wg.9.0 I I I 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380.0 EFPD ,,:
SOURCE. C-NRE.062.02.096 Rev 0 DAM May 8,1998 TIMR 11:56:05 PREPARERRebb DATP- C-498 REVIWER: WeR DATES -;1i Cycle 12 Fuel Excess Reactivity Worth -"Critical" Reference Condition 13.0 12.5 12.0 11.5 11.0 C.)4).1.Ca 10.5 10.0 9.5 9.0 8.5 8.0 7.5 7.0 6.5 6.0 5.5 5.0 4.5 4.0 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 V u 4.!; 1 8 i EFPD SOURCE C-NRE-06202m96 Rev 0 DATE: Apr 28. 1998 TlME 07:14:25 PREPARER:
0/_... DATE:4-+/-
9 El REVIEWER:
Q2,S DATE: 5f'lJq 12 DB-NE-06201 Revision 04 Cycle 12 Integral Worth of Soluble Boron 0 EFPD-10.0-9.5-9.0-8.5-8.0-7.5----1-4 ,.09--4 Z!b-00 A)-7.0-6.5-6.0-5.5.CRTIM-5.0-4.5 POWER I I I I I I I I I I-4.0-3.5-3.0-2.5-2.0-1.5-1.0-0.5 0.0 I I Soo I I I 0 100 200 300 400 600 700 800 900 1000 1100 1200 I 7 1300 1400 RCS Boron Concentration (ppmB)Figure 3 Page 1 of 21400 ppmB SOURCE: C-NRE0.02-096Rv 0 DATE Apr 28.1998 TME: 07:14:25 PREPARER:
-DATE: REVIEWER:
92>- DATE:6r414:jA 13 Cycle 12 DB-NE-06201 Revision 04 Integral Worth of Soluble Boron 0 EFPD-17.5-17.0-16.5-16.0-15.5-15.0 I-k -14.5< -14.0 13.5 O -13.0?8. .g-12.5-12.0 E -11.5 0 4 -11.0_5-4 A'- -10.5-10.0-9.5-9.0-8.5-8.0--CRITICAL-P(-7.5 I I I IT I 1200 1300 1400 1500 1600 1700 1800 I 2100 2300 I --2500 1900 2000 2200 2400 2600 RCS Boron Concentration (ppmB)Figure 3 Page 2 of 2 21200 ppmB SOURCE C-NRE.062.02096 Rev 0 DATE Apt 28,1998 TIMPN 09:00:05 PREPARER.- -AR4&-g-DAT-R REVIEWER:
-DATh- 1'1 t JA Cycle 12 Integral Boron Worth Correction Factor 0-S 00 I--, O0 e.LA b 1.20 1.19 1.18 1.17 1.16 1.15 1.14 1.13 1.12 1.11 1.10 1.09 1.08 1.07 1.06------1.05 1.04 1.03 1.02 1.01 1.00 0.99 LRIT.CAL I I 40 60 0 80 0 20 I I I I 100 120 140 160 I I 2 180 200 220 240 260 280 T0 300 I -I -l 320 340 360 380 EFPD SOURCE C.NlE-062.024096 Rev 0 DATEM Apr 28,1998 lTMEM 09:00:05 PREPARER:
;i/R:1 DA1T 2I REVIEWER:
Q>, DATEh /IST Cycle 12 Integral Boron Worth Correction Factor 1-40N 0I m 1-l IZ 1.26 -1.25 -1.24 -1.23 -1.22 -1.21 1.20 -1.19 -1.18 -1.17 -1.16 -1.15 -1.14 -1.13 -1.12 -1.11 -1.10 -1.09-1.08 -1.07 1.06-CRITICAL .VI I-RD... ...1.05 I .I- I I I I okIII I I I I I I I I 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 0 u 320 340 EFPD SOURCE: C-NRE.062.02-096 Rev 0 DATE Apr 28,1998 TIME: 14:39:46 PREPAREFL42/, DATE.4'-REVIEER: --DATE. f N4 Cycle 12 Differential Reactivity Worth of Soluble Boron"Critical" Reference Condition APSRs In 0 1-a I-10^ u 8 h;sm-0.0086-0.0085-0.0084-0.0083-0.0082-0.0081-0.0080-0.0079-0.0078-0.0077-0.0076-0.0075-0.0074-0.0073-0.0072-0.0071-0.0070-0.0069-0.0068-0.0067-0.0066-0.0065-0.0064----63 -0 EPPDI-0-4 0%~-500 FPD 400 ....I.. '' 11 1 4 '--1300ED I:.........I D:--r 0 I I 100 200 I I 300 400 500 600 I I I I I I I I I I I I I I I I I -I 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 T0 RCS Boron Concentration (ppmB)...1 SOURCM C-NRE-06202.096 Rev 0 DAMK Apr 28,1998 TIMM 14:39:46 PREPARER:
:,:WM -DATlD C-q-4yk REmEm wR: 922 -DATEllD!-
tL4 Cycle 12 Differential Reactivity Worth of Soluble Boron"Critical" Reference Condition APSRs Out 021 iIg 02-0.0092-0.0091-0.0090-0.0089-0.0088-0.0087-0.0086-0.0085-0.0084-0.0083-0.0082-0.0081-0.0080-0.0079-0.0078-0.0077-0.0076-0.0075-0.0074-0.0073-0.0072-0.0071-0.0070 I-.0 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 RCS Boron Concentration (ppmB)
SOURCE. C-NRE.062.02.096 Rev 0 DA'E: May 10, 1998 TIME: 14:29:06 PREPARER:
1f f DATE: S-10 -9'8 REVIEWER:
-p DATE:%lV-0.0079-0.0078-0.0077-0.0076-0.0075-0.0074_ -0.0073.0.0072-0.0071-0.0070 O -0.0069-0.0068 0-0.0067 J~-0.0066-0.0065-0.0064-0.0063-0.0062 ......-0.0061 -+-i-0.0060-0.0059 0 100 200 300 400 500 Cycle 12 Differential Reactivity Worth of Soluble Boron"Power" Reference Condition APSRs In 00 0V5 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 RCS Boron Concentration (ppmB)
SOURCE: C-NRE-062.02096 Rev 0 DATE May 10,1998 Md&E 14:29:06 PREPARER4 2 I DATE r-/o-F 9 REVIEWER: -S- .DATE:Et L(Cycle 12 Differential Reactivity Worth of Soluble Boron"Power" Reference Condition APSRs Out 14~01 Ce 80 0.ZI IN't~J-0.0086-0.0085-0.0084-0.0083-0.0082-0.0081-0.0080-0.0079-0.0078-0.0077-0.0076-0.0075-0.0074-0.0073-0.0072-0.0071-0.0070-0.0069-0.0068-0.0067-0.0066--eC--'0--PD-tIzIIW3II D EFPI:--r 0 I I I I I I I I I I I I I .100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 RCS Boron Concentration (ppmB)0~lI I I I I 1 1700 1800 1900 2000 2100 SOURCEh C-NRE-06202-096Rev0 DAMhD May S,1998 IMBE 12:03:48 PREPAREU I2l J DAT l44 REVEWER: R,-EI -DA1FJ- =RC Cycle 12 Minimum Boron Concentration to Assure 1% AK/K Shutdown Margin NO Known Stuck Rod 2100-2000 1900 1800-a l)0 0 U 1700 1600-T<300 "F 1500 0)I=P0-F < T <5001, 1400 1300 1200 1100 1000---0gS W (b 900 I I 80 100 I I I 0 20 40 60 120 140 160 180 I I 220 240 I I I 200 260 280 300 320 340 360 380 EFPD SOURCE. C-NRE-062.02.096 Rev 0 DAWl May 8, 1998 TnME 12.03:48 PREPARIER:
1 DATM .58 REVIEWER:
grit DA1lIEhl39h Cycle 12 Minimum Boron Concentration to Assure 1% AK/K Shutdown Margin NO Known Stuck Rod 1500 1400 1300 1200 C.-)0 00 m U 1100 1000 I< 300 -F 900 r <500 '800 I 700 600 500 400--300-I I I I I I I I I I 580 600 620 640 320 340 360 380 400 420 440 460 480 500 520 540 560 660 680 700 EFPD SOURCE C-NRE-062.02-096 Rev 0 DAM May 8, 1998 71ME, 1203:48 PREPARUER.
_W21 DATlD 4 &REVMWVER:
_ >8 DAT1D L15&Minimur 2200 2100 2000 1900 t 1800 o 1700 8 1600-1500 Pq 1400-__________________
U 1300 -1200 -1100- -LI I.. ______W 1000 130-Ai 0 20 40 60 80 100 Cycle 12 a Boron Concentration to Assure 1% AK/K Shutdown Margin ONE Known Stuck Rod O 120 140 160 180 200 220 240 260 280 300 320 340 360 380 EFPD as' '''SOtJRCE: C-NRE-062.02.096 Rev 0 DATE May 8.1998 TSME 12.03:48 PREPARER.
2WLVt EDAT R.-- 9 REVIEVNER:
-DAThlj!l1i9 Cycle 12 Minimum Boron Concentration to Assure 1% AK/K Shutdown Margin ONE Known Stuck Rod 1500-1400 1300 1200*.-I TV 0 Cd 001 0 U 1100-1000-T<300TF 900-WJ F r it U v 800 700-600 500 400--I 300 500 520.I I I I 1 540 560 580 600 620 I -- 6 660 680 700 0R 320 340 360 380 400 420 440 460 480 640 EFPD a1 SOURCE C-NRlE PREPARER:
el REVIEVER: 11900 -11850 -11800 -11750 -11700 -11650 -11600 -11550 -11500 -G) 11450 -11400-11350 -c 11300 -11250-11200-11150 -11100 -11050 -11000-10950 -10900 10850 10800 0D6202.096 Rev 0 DATh Apr 28,1998 lIME 16:36:03 SAv7 DATED SW-2 ,....... .... i f F +...........
...........
................. ......................... ....... .....Ull Cycle 12 RCS Water Volume vs. Pressurizer Levelwo LI.P .1 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300 310 320 330 340 350 360 370 380 -F 0 Pressurizer Level (inches)N1 SOURCE- C-NRE-062.02096 Rev 0 DATE: Apr 2X. :&deg; Tr PREPARER: .W DATE:.5-t-90 REVIEWER:
ki3 DATE: 5h 1qS 0 10 20 30 40 50 60 70 80 AM 07:21.52 25 Cycle 12 Integral Control Rod Worth Groups 5-7"Power" Reference Condition DB-NE-06201 Revision 04 APSRs In 240 250 260 270 280 290 300 1 I 1 I I I 1 90 100 110 I I I I I~ I 120 I I 4)A 4: 0.0-0.1-0.2-03-0.4-0.5-0.6-0.7-0.8-0.9-1.0-1.1-1.2-13-IA-1.5-1.6-1.7-1.8-2.0-2.1-2.2-2.3-2.4-2.5-2.6-2.7-2.8-2.9-3.0-3.1-3.2-33-3.4-3-5-3.6-3.7-3.8 130 140 150 160 170 180 190 200 210 220 230!I A I A I I i I I I I I I I I-RodIndex --H- H r -rI-I-200 EFPD 200 EFPD I I---400 EFPD 6 3 0 i -i i I-630 SED: 0 25 50 75 Control Rod Position (%WD)I IIII I 11 111 1 1 11 1 14 11 100 0 I I 25 50 75 100 GRP 5 0 25 50 75 100 GRP 7 GRP 6 Figure 8 Page 1 of 4 GRPs 5-7 APSRs In SOU{RCE. C-NRE-062.02-096 Rev 0 DATE: Apr 28.1998 TIME: 07:2152 PREPARER:
DATE:5-*2-9f D mFVlf17Dn.
r?-vst n -.r 01 26 1t~vL.:K vt% I r-.- I -f Vr%Cycle 12 Integral Control Rod Worth Groups 5-7'Power" Reference Condition 90 100 110 120 130 140 150 160 170 180 190 200 210 220 I I V I I I I I I I I I F DB-NE-06201 Revision 04 APSRs Out 230 240 250 260 270 280 290 300 I I I I 1 I 1 I 0 A-I 10 20 I I 30 40 50 1 I 60 70 80 I I I 0.0-0.1-0.2{13-0.4-0.5-0.6-0.7_ l-I I I f lII I I Rod Index I z I I-I-a~~el C,,-0.8-0.9-1.0-1.1-1.2-13-1.4-1.5-1.6-1.7-1.8-1.9-2.0-2.1-2.2-23-2.4-2.5-2.6-2.7-2.8-2.9-3.0-3.1-3.2-33-3.4-3.5-3.6-3.7-3.8 610 E-684 EFPD---11--_ .Control Rod Position (%WD)... IS !. ......._ ... .. ... ......-----------------I I 0 25 50 75 100 0 25 50 75 100...., GRP 5.....0 25 50 I I 75 100 GRP 7 GRP 6 Figure 8 Page 2 of 4 GRPs 5-7 APSRs Out SOURCE: C-NRE-062.02-096 Rev 0 DATEh Apr 28.1998 TlE, 07:2152 PREPARER:- -ae DATE:.4-Y-2,&
REVIEWER:
S2- DATE: '>h l R 27 Cycle 12 Integral Control Rod Worth Group 7"Power" Reference Condition 220 225 230 235 240 245 250 255 260 265 270 275 280 DB-NE-06201 Revision 04 APSRs In 285 290 295 300 I I I I I I I I I I I 0.00 1111 r 111111 Rod Index-0.05-0.10-0.15-0.20 40.25 0 EFPD-030.20EFPD ff -0.35< 4.40-045 i &55 4 -0.60 0.065 j 001 111111163 E 630 EFPD-0.70 4.75-08-0.85 40.90-0.95-1.00 I I I I I l 65 70 75 I I I 80 85 90 I I 22.5 25 30 35 40 45 overlap 50 55 60 95 100 Group 7 Position (% WD)Figure 8 Page 3 of 4 Group 7 APSRs In SOURCE C-NRE-062.02-096 Rev 0 DATE Apr 28.1998 TMqE- 07:21:52 PREPAREbic&sect;
--.M DATE: -REVIEWER: -g- DATE: eIA 1-6 28 Cycle 12 DB-NE-06201 Revision 04 APSRs Out Integral Control Rod Worth Group 7"Power" Reference Condition 245 250 255 260 265 270 275 220 225 230 235 240 I I I I 0.00-Rod Index I I 280 285 290 295 300 IL11 I I-0.05-0.10-0.15-0.20--I 0.25-030--0.35 ,, 4).45-0.450'S) -0.60 610 EFPD 684 E D-.65-.70-0.75-0.80-0.85 S0-0.95-1.01 I'I I -T 22.5 25 overlap 30 I I 50 I 35 40 45 55 60 65 70 I I I I 75 80 85 90 95 100 Group 7 Position (% WD)Figure 8 Page 4 of 4 Group 7 APSRs Out SOURCE- C-NRE-062.02-96 Rev 0 DATE Apr 28.1998 PREPARER R: Z~L 1 DATE: ,S.- 2 -0 REVIEWER :&#xa3;X. DATE: i-5]RlTIME: 07:43 37 29 DB-NE-06201 Revision 04 Cycle 12 Integral Control Rod Worth Groups 5-7 APSRs In"Critical" Reference Condition, NO Xenon 0 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300 ,1, ,1, 1Rod n _ _ _ d.5 et1 iIo IndeX- l1 ii lll lll ,zm 0 10 20 30 40 50 60 70 I I I I 10 0_W 4 0.0-0.1-0.2-0.3-0.4-0.5-0.6-0.7-0.8-0.9-1.0-1.1-12-13-1A-1.5-1.6-1.7-1S-1.9-2.0-2.1-2.2-2.3-2.4-2.5-2.6-2.7-2.S-2.9-3.0-3.1-3.2-3.3-3.4-3.5-3.6-3.7-3.8 I1 I I 1 _4 I I 33 I Ik I F 4,00 EFPD 3 w II II II 1630 EFPDI Coto Poito I I111111 WD 111.---0 25 50 G1RP GRP 5..75 0 100 25 I 0 75 25 01 100-J 50 7 GRP 7 7 100 50 GRP 6 l. .Figure 9A Page 1 of 4 GRPs 5-7 APSRs ln SOURCE.= C-NRE-062.02-096 Rev 0 DATE. Apr 28.1998 TMh8E: 07:43:37 PREPARER:
R. DATE: %-2-8 REVIEWER:
'. DATE: ':;3 I4y 30 Cycle 12 DB-NE-06201 Revision 04 APSRs Out Integral Control Rod Worth Groups 5-7"Critical" Reference Condition, NO Xenon 0 10 I I 20 30 40 I 1 I S0 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 1 1 1 1 1 I1 1 I I 1 1 220 230 I I 240 250 260 270 280 290 300 I I I I I I I I I I 6)S: CO 0.0 40.1-0.2-03-0.4-0.5-0.6-.7-0.8-0.9-1.0-1.1-1.2-13-1.4-1.5-1.6-1.7-1.8-1.9-2.0-2.1-2.2-23-2A4-2.5-2.6-2.7-2.8-2.9-3.0-3.1-3.2-3-3-3.4-3.5-3.6-3.7-3.8 1 I I I I I I 1-Rod Index Fz I I .I .I I .I .I i 610 EFPD 1 684 EFPD----------I-Control Rod Position (%WD) _ _ _ _ _ _ ._ _I I I I I I I I I f I I LI I I I I I I I I I I I- 1 --.I- I I I--t 0 25 50 75 I 100 I I 0 L 75 25 100 50 7 GRP 7 75 100.....GRP 5 0 25 50 6 GRP 6 Figure 9A Page 2 of 4 GRPs 5-7 APSRs Out SOURCE- C-NR&#xa3;E462.0496 Rev 0 DATE: Apr 28. 1998 T7ME 07:43:37 PREPARER:
..DATE:h .54--9 REVIEWER:
-DATE: 5L1I 31 Cycle 12 DB-NE-06201 Revision 04 APSRs In 220 225 230 235 244 Integral Control Rod Worth Group 7"Critical" Reference Condition, NO Xenon 245 250 255 260 265 270 275 Rod In 1, 1111111Rod Index -1 111 280 285 290 1 I 295 300 I 0.00-0.05--0.10-0.15-0.20--0.25 -1 1111111111
! i i ff 0 EFPD-030 -1200 EFPD ff -0.35 t -M.45 3 -0.55 4 -0.60-0.65-.70 075-0.80---400 EFPD-.85 T I I I llpI[ 630 EFPD I 4.9-95--10D I*I T 22.5 25 overlap I 30 35 40 I I I I I 65 70 75 I 45 50 55 60 80 85 90 95 100 Group 7 Position (% WD)Fwguxu 9A Page 3 of 4 Group 7 APSRs In SOURCE. C-NRE-062.02-096 Rev 0 DATE Apr 28. 1998 11E: 07:43:37 PREPARER:
DATE: .5 -A BTV'-V -)T. , AT.Ca -32 A.mVw-VVZK: UALE: --11111A-%Cycle 12 Integral Control Rod Worth Group 7"Critical" Reference Condition, NO Xenon DB-NE-06201 Revision 04 APSRs Out 220 225 230 235 240 245 0.00 250 255 260 265 11M11Rod Index R 270 275 I I 280 285 290 295 300 i I I-0.05--0.10-0.15-i-0.20-0.25 40.30-0.40-0.45~-0J30-0.55 4) -0.60-0.65-----610 EFPD-0.7-075-00--085-6841 L i-090-1.00 22.5 25 overlap I I I I I I I I I I 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 Group 7 Position (% WD)Figure 9A Page 4 of 4 Group 7 APSRs Out SOURCE C-NR; Z': -m096 Rev0 DATE: Apr 28. 1998 MIMER 07:53:14 PREPARER:
2Ls DATE: 4- yi2 REVIEWER:
Qg DATE: 13IY+/-33 Cycle 12 DB-NE-06201 Revision 04 APSRs In Integral Control Rod Worth Groups 5-7"Critical" Reference Condition, PEAK Xenon o 10 I I 20 30 40 S0 60 70 SO 90 100 I I I 110 I I I I 120 13 1+T 10 4)0.0-0.1-0.2-0.3-0.4-0.5-0.6-0.7-0.8 40.9-1.0-1.1-1.2-1.3-14-1.5-1.6-1.7-1.8-19-2.0-2.1-2.2-2.3-2.4-2.5-2.6-2.7-2.8-2.9-3.0-3.1-3.2-3.3-3.4-3-5-3.6-3.7-3.8 10 140 150 160 170 180 190 200 zI I HItzx I II Rod Index l lT ll200 EFPD 200 EFPD 210 220 230 240 250 260 270 280 290 300 i I i I I I I I I I i 400 EFPD-H H H i i +/- F l-630 EFPD 11111111111111111111111_
Control Rod Position (%WD)IIII Ii I L f II j I 0 25 50 75 100.....0 L 50 75 I I 25 100 50 1 GRP 7 75 100 GRP 5 0 25..GRP 6 Figure 9B Page 1of 4 GRPs 5-7 APSRs In SOURCE. C-NRE062.02-096 Rev 0 DATE. Apr 2S 1998 fME. 07:53:14 PREPARER:
.4 1 DATE: 5-1?13 REVIEWER:
\L$> DATE: Sh1*0c1'Integral"Critical" R 0 10 20 30 40 50 60 70 80 90 100 II(34 DB-NE-06201 Revision 04 Cycle 12 1 Control Rod Worth Groups 5-7 Reference Condition, PEAK Xenon 1 120 130 140 150 160 170 IS0 190 200 210 220 1 I- 1 I -I I I I I I APSRs Out I I I I I I I I 230 240 250 260 270 280 290 300 I I i I I I I e 0.8)60 0.0-0.1-0.2-0.3 0.4-0.5-0.6-0.7-0.8-0.9-1.0-L1-1.1-I1.2-1.3-IA-1.5-1.6 1.7-1.-1.9-2.0-2.1-2.2-2.3-2.4-2.5-2.6-2.7-2.8-2.9-3.0-3.1-32-33-3.4-3.5-3.6-3.7-3.S liii. l I I i-Rod Index -111111111-610 EFPD... ......-----684 E PD.i 11111111111111111111111lii Control Rod Position (%WD)ii, .iii tiiitl.0 25 50 75 100 0 0 L 25 50 75-1 100 x R lX GRP 5 0 25 50 I I 75 100 GRP 7 l GRP 6 Figure 9B Page 2 of 4 GRPs 5-7 APSRs Out SOIURCE C-NRE-062.02-096 Rev 0 DATE Apr 28.1998 TIME 08t01.34 PREPARER:
DATE: 94Y8_ s b zk I --.35 kRhVsbwtK:
Vc> AME _71t1811 Cycle 12 Integral Control Rod Worth Group 7"Critical" Reference Condition, PEAK Xenon DB-NE-06201 Revision 04 APSRs In 220 225 230 235 240 245 250 255 260 265 270 275 280 285 290 295 300 I I I I I I.1 I1 nt 1,,11 Rod Index:-0.05-0.10-0.15-0.20-0.25] O EFPD :.200 EFPD 40.30_ 111111111111111111
-0435-a4.O ,, 40.45 0 4 -0.60-0.65-.70-.75-0.80-0.85-0.90:400 BFPD-630 EFPD-0.95 I 111111 I I-1.00..... .i.... .I 22.5 25 30 35 40 overlap 45 I I 7 65 70 I 8 75 80 I I I 85 90 95 50 55 60 100 Group 7 Position (% WD)Figure 9B Page 3 of 4 Group 7 APSRs In SOURCE C-NRE-062.02-096 Rev 0 DATh Apr 28.1998 TWE 07:53:14 PREPARER:
: 2 1 DATE: 5- 9-S%REVEWER: K ;* DATE:____h__
36 Cycle 12 DB-NE-06201 Revision 04 APSRs Out Integral Control Rod Worth Group 7"Critical" Reference Condition, PEAK Xenon 220 225 230 235 240 245 I I 0.00 250 255 260 265 270 275 I1 1 r d 1 jtj+/- j Rod Index 1 T11 IITI I I 280 285 I I 290 295 300-0.05--0.10-0.15-0.20-0.25-0.30_ -0.35-1 -0.40.-0.45 0: -0.50-055 la s 8) -0.60-0.65-0.70------610 E PD L 4-075-0.0-0.85--]-0.I 684 EFPD oss5--1.00 I r I 35 I T 40 45 50 55 22.5 25 30 overlap I I I 7 60 65 70 75 I I 100 80 85 90 95 Group 7 Position (% WD)Figure 9B Page 4 of 4 Group 7 APSRs Out SOURCE: C-NRE-062m2-096 Rev 0 DATE: Apr 28.1998 TIME, 11:06:33 PREPARER:
g7 LDATE:L-REVIEWER:
+/- -DATE: 3 'A JIA 37 DB-NE-06201 Revision 04 Cycle 12 Adjusted Reactivity Worth of Control Rod Groups 1-7: R (for Shutdown Margin Calculations Only)"Critical" Reference Conditions
-5.70-5.60-5.50-5.40-5.30-5.20 i-s -5.10-5.00 4.90-4.80':4-M -4.70 p -4.60.4 -4.50 C.)2 -4.40-4.30 NO Known Stuck Rod----4.20-ONE Known Stuck Rod-4.10-4.00-3.90-3.80---3.70 I 20 0 20 40 I I I I I I I I I 80 100 120 140 160 180 200 220 240 I I I 360 60 260 280 300 320 340 EFPD Figure 10 Page 1 of 2360 EFPD SOURCE C-NE-062.02-096 Rev 0 DATEI Apr 2X.1998 TIIME I :06:33 PREPARER:LW 1 DATE: //REVIEWER:
kP, DATE E lj 38 DB-NE-06201 Revision 04 Cycle 12 Adjusted Reactivity Worth of Controi Rod Groups 1-7: R (for Shutdown Margin Calculations Only)"Critical" Reference Conditions
-5.90-5.80 I-5.70-5.60-5.50-5.40 0 P.A-5.30-5.20 NO Known Stuck Roc I-5.10--5s.0_4.90 4.80-4.70 4.60 4.50-4.40-4.30-4.20-4.10 C,:_lIIIllI#-
O KnownS cRod 11lfi ______ l ll l fit_ _____ l 1 IIIII IIIIII I I I II I I_ ~ ~ ~ I I llll&sect;lttillllle If IX f_t I _ f i l l I I I l l l
* W l l l l
* l l l I g l K B w l l_ 1 _ ' 1 1 f l l 1 I .I I .I I I .I I .I I I I I I I I I I
* I I I I I I I I_ _ II I * * *
* II 1 1 f I II.III.II1l
_ ____ '''' III ,, ,, ,, *,, * , ,,.f1ill.11111 11fi_
* I II I 1.i lIIIIIIIl IIII111 I _ _ llll i 11111l1l11111111111111111111111111111
_ 1_ II I I 1 zI i II II I I II I* _1 11 11 I I* II I* I II II
* I* LJ 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 EFPD 4.00-3.90 Figure 10 Page 2 of 2 2340 EFPD SOURCE. C-NRE-062.02(096 Rcv 0 DAM1E Apt 28,1998 TIME 10:01:02 PREPARER; DAIE:28 REVIEWER:
D ATES D lE.Al-0.32-0.30 TilI-0.28-0.26-0.24-0.22-0.20-0.16-0.14-0.12-0.10-0.08 Cycle 12'SR Reactivity Worth -"Critical" Reference Condition-0.06-0.04--0.02'11 0.00-85 90 95 100 I I I I I I I 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 Group 8 Rod Position (%WD)
SOURCE C-NRE-062.02.096 Rev 0 DAI Apr 28,1998 MTIM 10:01:02 PREPARER IL DATE CPO4 REVIEWER: (Z.t DA1DATE : Cycle 12 APSR Reactivity Worth -"Power" Reference Condition-0.32-0.30-0.28-0.26-0.24----0.22-0.20-0.18-0.16-0.14-0.12-0.10-0.08 I--I-Uk.-0.06-0.04-0.02 0.00 I I I I__ iIIIIIIIIIiIIIIIIII I I I I I I 19 1 N 111111E 50 55 60 65 70 75 80 85 90 95 100 E 0 0 5 10 15 20 25 30 35 40 45 Group 8 Rod Position (%WD)
SOURCE: C-NRE-062.02-096 Rev0 DAIER Apr 23,1998 1MM 10:27:26 PREPARMER1a_3..DATE.E?
28 REV EWE: (4P DT-fCt1 Cycle 12 Temperature Coefficient Group 1 @ 100% WD, 2-7 @ 0% WD, 5320F APSRs In.2 U 8 E_0.004 0.002 0.000-0.002-0.004-0.006-0.008-0.010-0.012-0.014-0.016-0,018-0.020-0.022-0.024-0.026-0.028-0.030 I I I I I I I I I I I t I I I I I t I I I I I f I I I I I I I I I I I I f I I I I I I I I I I I f I I I I I I I I I I I I I I I I I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 11 IIH IIIII H ill I I I I I I I I I ] J i l l:R fR R 444' I [Hill] 11 III HI I I I I I I I I IIII-LU 1 11111 III IIIIIIIH IIII I Jill I H H H H H H i IIIIIIIIIIII ill 11 I I I I If Ill.... ------IIII Hll 0 'or T -1 IA 'I-1 II Jill Jill o I I Hll I I I Jor I I lo-I 630 M D .. ....--------------
---------------------
I l l I J i l l 1 .1 1 HlH-------- -- woe,- I I Jill H ll -------------------- .l, I W ----- I .I I I II II 11......J i l l------- ---- It I I------- -0, If I I 11 II ol!ill;Pe ------------
-----------Po ---------------------
-----------TT_LLMAILLUZ
...I I I I l I I I I I I I 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 RCS Boron Concentration (ppmB).iz m.@
SOURCE C-NRE-062.02-096 Rev 0 DAMED Apr 28,1998 AMMD 10:27:26 PREPARER.
2M: o DAlE 9 REVMWER: <2Z> --DATE. fi QS Cycle 12 Temperature Coefficient Group 1 @ 100% WD, 2-7 @ 0% WD, 532 0 F APSRs Out 0.004 0.002 0.000 584 EFPD --0.002-0.004--G).1'41 0 0 Hd-0.006-0.008-0.010-0.012-0.014-0.016----0.018 -rW-0.020--0.022-0.024-0.026-0.028 --0.030 -<e I 3.jZ F 09 I I I I I I I I 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 I I I I I I I I I I 1 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 RCS Boron Concentration (ppmB)
SOURCE: C-NRE-062.02-96 Rev 0 DATE May 8,1998 TIME 12:26:38 PREPARER : DA1~TF W-- 59 REVMWER: _ _ DAT 5 J Cycle 12 Hot Standby Critical Boron Concentration CRG 1-6 @ 100% WD, CRG 7 @ 25% WD, APSRs @ Nominal HFP Position, NO Xenon, 532&deg;F Note: This is the Boron Concentration needed to establish criticality at 25% WD on Group 7 with NO Xenon and HFP equilibrium Samarium.
This concentration may be adjusted for Xenon and Rod Index variations.
2500 2400 2300 2200--0 I-i 0 C,, 8 c;1 m v8 go 2100 2000 1900 1800 1700 1600 1500 1400 1300-1200 V~Od -I W 1100 380 4, 0 20 40 60 80 100 I I I I I r 120 140 160 180 200 220 I I I r 280 300 320 340 240 260 360 EFPD SOURCK C-NRE.062.02.096 Rev 0 DAM1E May S. 1998 TIME 12 26:38 PREPARER:
;Y DATFl 5 , 49 REVIEEWER:
DAT Cycle 12 Hot Standby Critical Boron Concentration CRG 1-6 @ 100% WD, CRG 7 @ 25% WD, APSRs @ Nominal HEP Position, NO Xenon, 532&deg;F Note: This is the Boron Concentration needed to establish criticality at 25% WD on Group 7 with NO Xenon and HFP equilibrium Samarium.
This concentration may be adjusted for Xenon and Rod Index variations.
1700 II 1600 1500 1400 zz- Z 1300 1200 1100 -G) 1000 0 U 100 -800 Q 700 600 MZ 500 400 1)f 300 RIW30 340 30 380 40 420 40 460 40 500 50 540 50 580 60 620 60 660 60 700 40 44 48 520 560 600 640- 680ll~llllll EFPD SOURCE, c-NRE-062m-096 Rev 0 DAI Apr 28.1998 1IME 08:28:19 45 DB-NEA06201 PREPARER:
2Y7b!7 DATE: :/y&V9A Revision 04 REVIEWER:
?- __ DATE: Cycle 12A Cycles In Power Doppler Reactivity Deficit 3.1 -. .....3.0-2.9-2.8 -- ----2.7 2.6 -2.5 -M 2A 2.3 -630 2.-l1 ......i illlB ...tt ...2.1 20 400 2.05<1.9~1.8-1.7 -...20EP 1.6-1.4 5 Powe Lee (%FP)0iul 1.4 Pag 1.2&#xa3;1.0-0.9 0.8-0.7 0.6 -..0.5-04 5-0 15 2 25 30 3.4.55.5.0.5 707.0 5 9 9 0 Power Leel.(..P 0Figure.14 Page 14o APSRs In SOuRCE: C-NRE-062.02-096 Rev 0 DATE: Apt 28.1998 lBIE: 08:28:19 PREPARER:
Y? DATE: / e//REVIEWER:
2.5. DATE: '-3 4XJ Powe 46 DB-NE-06201 Revision 04 APSRs Out Cycle 12 er Doppler Reactivity Deficit 3.1 3.0 2.9 2.8 2.7 2.6 2.5 2.4 2.3_4_4 e -0 a a.)0 0 04 2.2 2.1 2.0 1.9 1.8 1.7 1.6 1.5 1.4 1.3 1.2 1.1 1.0 0.9 0.8 0.7 0.6 0.5 0.4 0.3 0.2 0.1 0.0 684 EFPD 610 EFPD I I 1 I ---I I- -1 I I I I I I -- -----I --0 S 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 Power Level (%FP)I I 7 90 95 100 Figure 14 Page 2 of 2 APSRs Out SOURCE C-NRE062.02.096 Rev 0 DAIE May 8,1998 TlME 12:03:48 PREPARER:
2i/ DATE SI &i- 8 REVIEWER: (borer DATE: Llq-C1'6 Cycle 12 Minimum Boron Concentration to Ensure 1% AK/K Shutdown Value CRG 1 @ 100% WD, CRG 2-7 @ 0% WD, NO Xenon, No Stuck Rod Assumed 2100 2000 I 1900 8 02 U 04 1800 1700 1600 Aiii liii I I I I I _ _ = _ _ i i _ _ ___l 111 I FI I, I I I I II I I I I I II, 1500-O"F! T <5007F 1400 1300 1200 1100-1000 0 20 I I I I I 140 I I I I _280 300 320 340 360 40 60 80 100 120 160 180 200 220 240 260 tA -0 _qj W C, 00 0 CD 21 E EFPD NOTE: When this graph is used, put an Information Tag on the Diamond T-handle indicating this concentration allows only Group I to be pulled while still maintaining the reactor 1% shutdown (i.e., 1%AK/K Shutdown Value).380 g t:;I 0o SOURCE C-NREM062.02-096 Rev 0 DATE: May 8,1998 TMEE 12:03:48 PREPARERZI DATE: 98 REVIEWER:
9tZS, -DATE: q Cycle 12 Minimum Boron Concentration to Ensure 1% AK/K Shutdown Value CRG 1 @ 100% WD, CRG 2-7 @ 0% WD, NO Xenon, No Stuck Rod Assumed 1400 1300 1200 0 0 U 01 t0 U 1100 1000 T<300TF 900-`lWloil t i r t L1'i I I I I I I IIIIIIII I I It iW rs 800 700 600---500 400--300-I I I I I 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 EFPD 700 0 NOTE: When this graph is used, put an Information Tag on the Diamond T-handle indicating this concentration allows only Group I to be pulled while still maintaining the reactor I % shutdown (i.e., 1%AK/K Shutdown Value).
SOURCE: G-NRE-062.02-096 Rev 0 PREPARER:My&~
DATE: -//z/9g REVIEWER:
t DATE: 51fla kN 49 DB-NE-06201 Revision 04 Figure 17A Cycle 12 Axial Power Imbalance Operating Limits and RPS Axial Power Imbalance Allowable Values 4-Pump Operation See Core Operating Limits Report (Figures 4a, 4b, 4c and 6)Figure 17A SOURCE: C-NRE-062.02-096 Rev 0 PREPARER:
my DATE: -Z&SQ REVIEWER:
\7>F. DATE:,^h.\--
50 DB-NE-06201 Revision 04 Figure 17B Cycle 12 Axial Power Imbalance Operating Limits and RPS Axial Power Imbalance Allowable Values 3-Pump Operation See Core Operating Limits Report (Figures 4d, 4e, 4f and 6)Figure 17B SOURCE: C-NRE-062.02-096 Rev 0 PREPARER:
Ai DATE: J/,z/9A REVIEWER:
>S DATE:-s4,t7 51 DB-NE-06201 Revision 04 Figure 18A Cycle 12 Regulating Group Position Operating Limits 4-Pump Operation See Core Operating Limits Report (Figures la, lb, 1c)Fgure 18A SOURCE: C-NRE-062.02-096 Rev 0 PREPARER: ,A DATE: Ls-/ z9 REVIEWER:
Q-b DATE: .s$,gk 52 DB-NE-06201 Revision 04 Figure 18B Cycle 12 Regulating Group Position Operating Limits 3-Pump Operation See Core Operating Limits Report (Figures ld, le, 1f)Figure 18B SOURCE: C-NRE-062.02-96 Rev 0 PREPARER:
rA DATE: S /h2/9 REVIEWER:
Th -DATE: '4sis4 53 DB-NE-06201 Revision 04 Figure 19 Cycle 12 APSR Position Operating Limits See Core Operating Limits Report (Figure 3)Figure 19 SOURCE: C-NRE-Ca2.C--096 Rev 0 PREPARER:7i44 DATE: 5-q-9e REVIEWER:
DAw) DATE: 5fG#54 DB-NE-06201 Revision 04 Table 1 Cycle 12 Miscellaneous Physics Data Description J Value Units Flux Redistribution Penalty 0.300' %Ak k Safety Rod Worth Group 1-4 (CRG 1-4 inserted)
-3.12 %Ak Group 2-4 (CRG 1 withdrawn)
-2.35 %Ak k Conversion 33.446 MWd/mtU Beginning-of-Cycle Burnup 16,807 MWd Transient Poison Conversion Factor 80 -110 (PCF) Ak'A value of 0.0 %Ak/k may be used at 0 EFPD.END Table 1}}

Latest revision as of 20:52, 3 October 2024

Operator Licensing Examination Administered Septmber 13-20,1999 at DAVIS-BESSE, Docket NO.50-346
ML993480343
Person / Time
Site: Davis Besse Cleveland Electric icon.png
Issue date: 11/15/1999
From: Bies M
NRC/RGN-III
To:
NRC/OCIO/IMD/RMB
References
-RFPFR
Download: ML993480343 (657)
v • d • e


Text

Retrieved from "https://kanterella.com/w/index.php?title=ML993480343&oldid=3669333"