ML052710205
| ML052710205 | |
| Person / Time | |
|---|---|
| Site: | Arkansas Nuclear  |
| Issue date: | 09/15/2005 |
| From: | Gody A Operations Branch IV |
| To: | Forbes J Entergy Operations |
| References | |
| 50-313/05-301, ES-301-1 50-313/05-301 | |
| Download: ML052710205 (285) | |
Text
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ES-301 Administrative Topics Outline Form ES-301-1 Facility: ANO-1 Date of Examination: 9-12-05 Examination Level (circle one): Operating Test Number: 1 Type Administrative Topic Describe activity to be performed code*
(see note)
Conduct of Operations Ability to use plant computer to obtain and evaluate AIJPM-RO-PMSI Rev. 2 Conduct of Operations AIJPM-RO-RBAL3 Rev. 1 Equipment Control 2.2.26 AIJPM-RO-REFULI Rev. 0 (Imp 2.5)
Radiation Control Ability to control radiation releases.
DIPIS A1JPM-RO-RADI Rev. 2 2.3.1 1 (Imp 2.7)
Emergency Plan NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when all 5 are required.
Type Codes & Criteria: (C)ontrol room (D)irect from bank (5 3 for ROs; 5 4 for SROs)
(N)ew or (M)odified from bank (2 1 (Pfrevious (2 1; randomly selected)
(S)imulator ES-301, Page 22 of 27
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-PMSI Page 1 of 4 UNIT: 1 REV # 2 DATE:
TUOI NUMBER: A1JPM-RO-PMSI SYSTEMIDUTY AREA: ADMINISTRATIVE TOPIC - CONDUCT OF OPERATIONS TASK: OPERATE THE PLANT COMPUTER JTA#: ANOI-RO-PMS-NORM-4 KA VALUE RO: 3.0 SRO: 3.0 I<A
REFERENCE:
2.1 . I 9 APPROVED FOR ADMINISTRATION TO: RO: X SRO:
TASK LOCATION: INSIDE C R : X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM: X APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES REFERENCE(S): 1105.010. Cha. 011-00-0 EXAMINEE'S NAME: SSN -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THlS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THlS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-RO-PMSI Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: The plant is at 100% power operations. The Makeup Tank level is at 60 inches. RCS boron concentration is 1000 ppm. BAAT boron concentration is 12,000 ppm.
TASK STANDARD: The examinee uses the plant computer "BORON" proqram to calculate a total addition to the Makeup Tank of aporoximatelv 600 to 630 qallons consistina of 50 to 52.5 oallons boric acid and 550 to 577.5 oallons of Dl water.
TASK PERFORMANCE AIDS: 1105.010. Plant Monitorina Svstem NOTE: 1105.010 provides instructions for the Plant Monitoring System but the exact manipulations of this task are within the "skill of the craft." Therefore, procedure in hand is not required.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-RO-PMSI Page 3 of 4 INITIATING CUE:
The CRS directs you to use the plant computer to calculate a "No Concentration Change" to raise the Makeup Tank level to -80 inches.
CRITICAL ELEMENTS (C) 2. 3. 4. 5 1 (c) I PERFORMANCE CHECKLIST STANDARD NIA SAT UNSA T
keyboard.
1 /(C) 2 Select BORON program. 1 Selected BORON program on PMS 1 1 I
- 3. Select option No. 5, No Typed "5" and pressed ENTER key Concentration Change. on PMS keyboard.
- 4. Select option 0, boric acid and Dl Typed "0"and pressed ENTER key water addition. on PMS keyboard.
- 5. Enter values requested by BORON Examinee entered the following program. values:
Makeup volume required (gallons) = 600 to 630 (trainee should calculate the value needed using 20 inches x 30.86 gallonslin.)
Makeup boron concentration required (ppm) = 1000 Available feed solution Boron concentration (ppm) = 12,000 The PMS displayed the following values after entry of final value:
Feed volume Dl HZ0 550 to 577.5 gallons Feed volume boric acid 50 to 52.5 gallons END
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-RO-PMSI Page 4 of 4 EXAMINEE'S COPY JPM INITIAL TASK CONDITIONS:
The plant is at 100% power operations.
. The Makeup Tank level is at 60 inches.
RCS boron concentration = 1000 ppm BAAT boron concentration = 12,000 ppm INITIATING CUE:
The CRS directs you to use the plant computer to calculate a "No Concentration Change" to raise the Makeup Tank level to -80 inches.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RBAL3 Page 1 of 5 UNIT: 1 REV # 1 DATE:
TUOI NUMBER: A1JPM-RO-RBAL3 SYSTEMIDUTY AREA: ADMINISTRATIVE TOPIC -CONDUCT OF OPERATIONS TASK: ESTIMATE BORON CONCENTRATION REQUIRED TO MAINTAIN SHUTDOWN MARGIN DURING HEATUP USING RHOBAL PROGRAM JTA#: ANOI-RO-OPROC-NORM-70 KA VALUE RO: 3.9 SRO: 4.0 KA
REFERENCE:
2.1.23 APPROVED FOR ADMINISTRATION TO: RO: x SRO: X TASK LOCATION: INSIDE C R : X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): N/A EXAMINEE'S NAME: SSN -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THlS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THlS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RBAL3 Page 2 of 5 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: The olant is oreparina for startup after a reactor trip. The plant had ooerated continuouslv at 100% oower since the refuelina outaae EFPD = 0. RCS Tave = 185°F. Desired final RCS Tave = 534" Heatup is scheduled to commence later today.
TASK STANDARD: The examinee has calculated the reauired Boron concentration to maintain shutdown mamin durina heatuo usina RHOBAL and determined the value to be 1570 to 1578 oom.
TASK PERFORMANCE AIDS: Personal comouter with RHOBAL oroaram available.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-REAL3 Page 3 of 5 INITIATING CUE:
The Control Room Supervisor directs you to calculate Boron concentration required to maintain shutdown margin during heatup to 534°F using the RHOBAL program.
CRITICAL ELEMENTS (C) 1,2.5
- 1. Activate "Shutdown Margin" on pull Clicked (or Alt S via keyboard) on down menu. Shutdown Margin" in menu bar.
- 2. Run program to determine Boron Performed the following actions:
concentration required to maintain Clicked on Worksheet 5, "Boron shutdown margin. Concentration Required to Maintain SDM during Cooldown
. or Heatup".
Entered 0 for "Cycle Burnup in EFPD".
Entered 0 for all CRA positions, except 30.4 for APSRs.
Entered 185 for "RCS Average Temperature in degrees F".
Entered 534 for "Final Desired RCS Average Temperature in degrees F".
I -- .
- I I NOTE: Step 3 may be performed prior to step 1 via the "Poison" menu.
-r----
I I 3. Activate "Xenon and Samarium" menu.
I Clicked (or Alt P via keyboard) on "Xenon and Samarium" in menu bar.
I I 1 Performed the following actions:
Entered 0% "Power Level" Entered today's date.
Entered 0 for "Burnup" Clicked on "Beginning of cycle concentrations".
Clicked on "INITIALIZE
. POISONS" button.
Close 'Xenon and Samarium" menu.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RBAL3 Page 4 of 5 (C) I PERFORMANCE CHECKLIST I STANDARD I N/A I SAT ( UNSAT I I I I
- 5. Determine required Boron Noted the "required Boron conc from concentration. Table or Figure B6" to be 1574.
Candidate may discuss different boron concentration requirements for the various temperature ranges during heatup.
Accept 1570 to 1578 for final minimum boron concentration at 534°F.
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-RO-RBAL3 Page 5 of 5 EXAMINEE'S COPY JPM INITIAL TASK CONDITIONS:
The plant is preparing for startup after a refueling outage.
The plant had operated continuously at 100% power prior to the refueling outage.
. EFPD= 0 RCS Tave = 18YF Final RCS Tave = 534°F Heatup is scheduled to commence later today.
INITIATING CUE:
The SMICRS directs you to calculate Boron concentration required to maintain shutdown margin during heatup to 534°F using the RHOBAL program.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-REFULI Page 1 of 4 UNIT: I REV # &.-.- DATE:
TUOI NUMBER: A1JPM-RO-REFULI SYSTEMIDUN AREA: ADMINISTRATIVE TOPIC - EQUIPMENT CONTROL TASK: Perform Attachment B of 1502.004, Refuelina Boron. Temaerature, Tritium. and Level Check JTA#: ANOl-RO-FUELH-NORM-25 KA VALUE RO: 2.5 SRO: 3.7 KA
REFERENCE:
2.2.26 APPROVED FOR ADMINISTRATION TO: RO: X SRO:
TASK LOCATION: INSIDE CR:- OUTSIDE CR: BOTH: X SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1502.004. Cha. 034-02-0 EXAMINEE'S NAME SSN -
EVALUATOR'S NAME THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THlS JPM AND IS DETERMINED TO BE, SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THlS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-REFULI Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: A refuelinq outaae is in oroaress. Fuel handlina is in proaress.
TASK STANDARD: The examinee has correctlv identified that VEF-15 should be runnina and stated the reauirements of note 3 of At!. B.
TASK PERFORMANCE AIDS: 1502.004 Att. B
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-REFULI Page 3 of 4 INITIATING CUE:
The CRS asks you to review Att. B of 1502.004, Control of Unit 1 Refueling, which has just been completed by a license candidate. Determine if refueling requirements have been met.
CRITICAL ELEMENTS (C) 2 I (c) 1 PERFORMANCE CHECKLIST STANDARD NIA SAT UNSA T
- 1. Review the completed Att. B of Examinee reviewed the attachment.
1502.004.
- 2. Identify errors. Examinee identified the following:
- 1. VEF-15 FAN ON box not checked.
- 2. NIA entered under RECORD FLOWRATE for VEF-15.
RB purge should be isolated.
a tritium sample of refueling canal water obtained.
Shiftly tritium sampling of RB atmosphere commenced.
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-RO-REFULI Page 4 of 4 EXAMINEE'S COPY JPM INITIAL TASK CONDITIONS:
. A refueling outage is in progress Fuel handling is in progress.
INITIATING CUE:
The CRS asks you to review An. B of 2502.004, Control of Unit 1 Refueling, which has just been completed by a license candidate. Determine if refueling requirements have been met.
PROCNVORK PLAN NO. PROCEDURUWORK PLAN TITLE PAGE: 28 of 44 1502.004 COMTROL OF UNIT 1 REFUELING CHANGE! 034-0213 I I I I ATTACHMENT 9
?age 1 of 3 REFUELING BORON, TEMPERATURE, TRITIUM, AND LEVEL CHECK BORON SAMPLE wcad#2.9ipn SBIFTLY RB ATMOSPHERE TRITIUM CHECK ( 3 )
I F RB Purge i n o p e r a t i o n , THEN N/A.
SHIFT TIME SAMPLE POINT RESULTS DAYS A /6
( N o t e s o n riext pages)
PROC.MIORK PLAN NO. PROCUlURUWMlK PLAN TITLE:
PAGE: 29 of 44 1502.004 CONTROL OF UNIT 1 REFUELING ctinrroe 034-02-0 ATTACHMENT B Page 2 of 3 Log date and time of system startup following last test in the Chronological Log. Log indicated F5 Purge flow rate after system startup and each time that major flow changes occur such as opening equipment hacch, etc.
IF Systems are secured, THEN log date and time in Chronological Log, and log date and time of subsequent startup.
VEF-14 A/Y flowrate from SYING 3. VEF-15 from SPING 1.
During fuel handling, F5 purge shall be operable, and should be in operation. RB purge is inoperable, TfiEN enter TRN 3.6.1 Condition A, and either cease fuel movement, or isolate the RB purge system, obtain 1 tritium sample of refueling calla1 water, and commence shiftly tritium sampling of F5 atmosphere.
The Fuel Hsndling Area Ventilation System (FHAVS) shall be operable and in operation during movement of irradiated fuel assemblies in the fuel handliiig area ITS 3.7.12). IF VEF-14A/B flow rate degrades to outside required band, THEN enter TS 3.7.12 Condition A, stop irradiated fuel movement, and reset dampers per Initial Conditions of Control of Fuel and Control Rod Movement in U-1 Spent Fuel Area 11502.0101.
Log completion of requirements for this date in Attachment C.
IF sampling indicates that the concentration is dropping unexpectedly, is below the Refueling Boron Concentration, (from Reactivity Balance Calculation, 1103.015, Worksheet 5 or 6)
THEN secure all fuel movement, and initiate boration to greater than the Refueiing Boron Concentration. Boration shall be from the BAAT to the suction of DH Pumps per 1104.006.
Use available indication that is represeritative of RCS temperature. Prefer installed TI-1404 and TI-14Cj. Note instrument used in header.
Use available indication that is representative of lake temperature from one of the following locations. Note instrument used in header.
Unit 1 plant computer (T3640, T3642, T3644 or T3616). Ensure associated waterbox is in-service Unit 2 plant computer (T1430, TI436 or T1442). Ensure associated SW pump is in-service.
PROCMORK PLAN NO. PROCEDVRUW[)RK PLAN nN: PAGE: 30 of 44 1502.004 CONTROL OF UNIT I REFUELING CHANGE: 034-025 ATTACHYENT B Page 3 of 3 (9) WZiE! SF-45 c l o s e d , o b t a i n b o t h SFP and T r a n s f e r Canai l e v e l .
SF-45 open, o b t a i n e i t h e r SFP o r T r a n s f e r Canal l e v e l and N / A t h e o t h e r iiri t h i s c a s e e i t h e r reading w i l l s a t i s f y SR 3.9.6.1).
(10) SAR minimum l e v e l i s b a s e d upon m a i n t a i n i n g 23 f e e t over i r r a d i a t e d f u e l a s s e n h l i e s i n t h e Spent Fuel Pool s t o r a g e racks.
(11) D a i l y determine i f purge flow r a t e has v a r i e d by g r e a t e r t h a n 1300 cfm. Compare logged v a l u e s t o v a l u e s recorded i n c h r o n o l o g i c a l l o g ( e n s u r e con~parisoni.s made between s i m i l a r c o n d i t i o n s , i . e .
VEF-15 and VSP-2 i n o p e r a t i o n equipment h a t c h open would n o t be comparable t o same c o n d i t i o n s w i t h equipment h a t c h c l o s e d . IF v a l u e s v a r y g r e a t e r t h a n 1300 cfm from recorded v a l u e s , c o n t a c t SYE t o determine impact.
(12) IF Temporary A l t e r a t i o n 1104.ii28 Attachment B modifying S e r v i c e Water O u t l e t of E-28C i s ill serlrice, THEN SW p r e s s u r e must b e v e r i f i e d a s meeting t h e r e q u i r e x e n t s of t h e Terporary A l t e r a t i o n . This r e a d i n g i s r e q u i r e d t o v e r i f y l i m i t s of TRM F i g u r e 3.7.3-1 a r e maintained. Reference 1104.028 Attachment B t o determine which i n d i c a t o r ( ? P - 3 8 4 0 / P I - 3 6 0 7 / P I - 3 5 0 8 ) i s r e q u i r e d t o b e monitored. It may be r e q u i r e d t o v a l v e i n "-3340 temporary p r e s s u r e gauge t o o b t a i r , t h i s r e a d i n g . Obtain inclependent v e r i f i c a t i o n o f gauge i s o l a t i . o n i f P?-3840 was valved i n .
Performed by V
Reviewed b y - Date Time SRO i n Charge of Fuel Handling, CRS, o r SM
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-RO-RADI Page Iof 4 UNIT: 1 REV # 2 DATE:
TUOI NUMBER: A1JPM-RO-RADI SYSTEMIDUTY AREA: ADMINISTRATIVE TOPIC-RADIATION CONTROL TASK: ABILITY TO CONTROL RADIATION RELEASES.
JTA#: ANOI-WCO-CZ-NORM-11 KA VALUE R O : 2 , 7 SRO: 3.2 KA
REFERENCE:
2.3.11 APPROVED FOR ADMINISTRATION TO: RO: X SRO:
TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: X SRO: NIA ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE: LAB:
TESTING METHOD: SIMULATE: X PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1104.020. Cha. 042-00-0. P-47B Pump Differential Pressure versus Flow Rate oraoh EXAMINEE'S NAME: SSN EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THlS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RADI Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist System Walkthrough" portion of 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: Plant is shutdown for a Refueling Outaae. Circulatina Water P U ~ D P-3A in service. ALL other Circ Water Purnos are OOS for maintenance. Dischame flow to flume indicator (Fl-4642) is INOPERABLE and 0 0 s . T-16B TWMT release is in proaress. Maximum allowable flow rate for the release from Preliminarv Reoort is 90 apm. WCO reoorts CV-4642. CZ Discharae to Flume Flow Control Valve. is throttled ooen. WCO reports that P-476, Treated Waste Monitorina Pumo, parameters afler establishina flow throuah CV-4642: Suction Pressure = 10 osia. Discharae Pressure = 38 osia.
TASK STANDARD: Candidate estimates release flow rate between 75 to 85 aom and is within the allowable flow rate soecified in the Preliminary Reoort.
TASK PERFORMANCE AIDS: 1104,020. Att. "82.Offsite Dose Calculation Manual fODCM) and P-47B Pumtt Differential Pressure versus Flow Rate araoh.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-RO-RADI Page 3 of 4 INITIATING CUE:
The CRS directs you to perform step 4.15.1 of 1104.020 Att. "82" Treated Waste Monitor Tank (TWMT) T-I68 Liquid Release Permit and report if the release flow rate is within the allowable limit.
CRITICAL ELEMENTS (C): 2,4
- 1. Perform step 4.15.1.A Fl-4642 Recognized actions for inoperable inoperable actions. flow indicator contained in ODCM App. 1 Table 2.1-1. - - -
- 2. Determine required actions for Utilized procedure to ensure conducting release with Fl-4642 compliance with ODCM App, 1 Table inoperable. 2.1-1 Action 2. Determined release flow rate required to be estimated at least once every four hours utilizing
/
oumo curves.
Note Candidate should discuss options available to obtain pump curve data which may include any of the following:
- 1) Contacting System Engineer 2) Reference Pump Technical Manual.
with copy of P-478 Pump Curve upon request.
- 3. Obtain pump curve data to estimate Candidate obtained pump curve data.
release flow rate.
I I I I I I Note: Pump Suction and Discharge pressure are give,? in Initial Task Conditions.
- 4. Determine pump flow rate based on Candidate calculated pump pump differential pressure. differential pressure and estimates a C flow rate of 70 to 80 gpm using pump - - -
curve.
I 1 5. Report that flow is within allowable Candidate reported to CRS that flow is within allowable limit.
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-RO-RADI Page 4 of 4 JPM INITIAL TASK CONDITIONS:
Plant is shutdown for a Refueling Outage.
Circulating Water Pump P-3A in service. ALL other Circ Water Pumps are 00s for maintenance.
Discharge flow to flume indicator (Fl-4642) is INOPERABLE and 00s.
T-16B TWMT release is in progress.
Maximum allowable flow rate for the release from Preliminary Report is 90 gpm.
WCO reports CV-4642, CZ Discharge to Flume Flow Control Valve, is throttled open.
WCO reports that P-47B, Treated Waste Monitoring Pump, parameters after establishing flow through CV-4642:
Suction Pressure = 10 psig Discharge Pressure = 38 psig INITIATING CUE:
The CRS directs you to perform step 4.15.1 of 1104.020 Att. " B 2 Treated Waste Monitor Tank (TWMT) T-16B Liquid Release Permit and report if the release flow rate is within the allowable limit.
Treated Waste Monitor Pump P-476 0 2'0 40 6'0 80 100 120 140 160 Flow GPM (5 GPM increments)
PROC.iWORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 97 Of 122 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042-00-0 ATTACHMENT B2 Page 1 of 9 TREATED WASTE MONITOR TANK (TWMT)
T-16B LIQUID RELEASE PERMIT PERMIT # 1-LR-2005-0100 (Assigned by Chemistry) 09/12/2005 Date INITIALS 1.0 REQUEST (Operations) 1.1 T-16B taken out of service and placed on recirc for sampling and release:
SRP Date 09/12/2005 Time 0010 NOTE Tag contains information to remind personnel that tank is isolated for chemistry sample.
1.2 Verify Treated Waste Monitor T-16B Inlet (CZ-47B) is closed SRP and tag is installed on handwheel chain operator.
1.3 Initial T-168 level 92 %. Record local -
or SRP remote level indication. (Circle one) 1.4 IF Liquid Radwaste Process Monitor (RI-4642) is available, THEN perform the following:
1.4.1 Verify RI-4642 operable by performing one of the following::
A IF monitor count rate is 5 1000 cpm,
- perform the following:
THEN
- 1. Verify no Liquid Release in progress using FI-4642.
- 2. Select "Check Source" on RI-4642 and verify that the monitor responds to check source with a count rate rise
>lo0 cpm.
SRP B. IF monitor count rate >lo00 cpm,
- verify that count rate is <4.2236 cpm.
THEN 1.4.2 IF RI-4642 is operable,
- SRP THEN record Rad Monitor RI-4642 background counts and continue. 1.0 E4 cprn 1.4.3 IF RI-4642 is inoperable,
?;riEN notify Chemistry and continue.
PROC.MTORK PLAN NO. PROCEDURUWORK PLAN TITLE: PAGE: 98 of 122 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042-00-0 ATTACHMENT 82 Page 2 of 9 1.5 Record the following: SRP 1.5.1 # of CW Pumps running 1 and CW
- pump Disch Press 1.1 psig 1.6 -
IF adjustments are made to CW flow, THEN terminate
- release.
1.7 Submitted to Chemistry for Analysis, Section 2.0. SRP Date 9/12/2005 Time 0120 Section 1.0 Performed By Steven R. Pullin 2.0 Analysis (Chemistry) 2.1 Tank T-16B sample obtained for release analysis. JB Performed by John Brown 2.2 -
IF required for weekly sample for oil and grease, -N/A THEN Tank T-16B sample obtained. Otherwise N/A.
Performed by N/A 2.3 T-16B pH analysis performed by John Brown JB 2.4 IF
- pH is not between 6.0 and 9.0, N/A THEN adjust per Sampling the Treated Waste Monitor Tanks (T-16A/B) (1607.009). Otherwise N/A.
2.4.1 Tank T-16B post neutralization pH sample, N/A Obtained by N/A 2.4.2 T-16B post neutralization pH sample, N/A Analysis performed by N/A 2.4.3 T-16B post neutralization pH N/A 2.4.4 IF pH is not between 6.0 and 9.0, N/A THEN re-perform adjustment and analysis sequence until pH is between 6.0 and 9.0. Otherwise N/A.
2.5 Gamma spectroscopy performed by John Brown 2.6 Gamma spectroscopy report reviewed by Jim Smith 2.7 Tritium analysis performed by John Brown
PROCJWORK PLAN NO. PROCEDUREMJORK PLAN TITLE: PAGE: 99 of 122 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042-00-0 ATTACHMENT B2 Page 3 of 9 2.8 IF Liquid Radwaste Process Monitor (RI-4642) is inoperable
- N/A or unavailable as identified in "Request" or "Verification of Pre-Release Requirements" sections of this permit, THEN the following ODCM App. 1, Table 2.1-1 requirements shall be met. Otherwise N/A.
2.8.1 An independent sample of the tank contents shall be obtained and analyzed.
Performed by N/A 2.8.2 Computer input data shall be independently verified correct.
Performed by N/A 2.9 Sample results indicate release of total tank contents will JB not violate AN0 radioactive effluent discharge limit.
2.10 Preliminary release report prepared by John Brown
- not radioactive THEN N/A.
IF 2.11 Preliminary release report and/or permit returned to Control Room.
By John Brown Date 09/12/05 Time 0700 3.0 Verification of Pre-Release Requirements (Operations) 3.1 Verify CW flow/configuration recorded in initial release SRP submittal data is still valid.
3.2 Verify appropriate signatures on preliminary report. SRP 3.3 CRS/SM approval to proceed with release CRS/SM Ahel Leader 3.4 Provide copy of Setpoints section from Preliminary Report SRP to Control Room Operators.
3.5 Verify F560 in service by performing the following:
3.5.1 Verify open:
SRP CZ-74 (LRW Disch Filter F-560 Inlet)
CZ-77 (LRW Disch Filter F-560 Outlet) SRP 3.5.2 Verify closed CZ-83 (LRW Disch Filter F-560 SRP Bypass!
PROC.MTORK PLAN NO. PROCEDURWORK PLAN TITLE: PAGE: 1 0 0 Of 122 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042-006 ATTACHMENT 82 Prige 4 of 9 3.6 IF Liquid Radwaste Process Monitor (RI-4642) is operable and available, THEN verify proper operation of radiation monitor and interlocks as follows. Otherwise N/A.
3.6.1 Check Liquid Radwaste Process Monitor (RI-4642) SRP available by one of the following methods:
IF monitor count rate is 2 1000 cpm, THEN select CHECK SOURCE on RI-4642 and verify that the monitor responds to check source with a count rate rise >I00 cpm.
IF monitor count rate >I000 cpm,
- verify that THEN count rate is <4.2236.
3.6.2 Verify the following valves closed:
FWMT Disch to CW Flumes (DZ-25) SRP LZ Drain Pump P-45 Discharge to Flume (LZ-5) SRP Treated Waste Discharge to Circ Water Flume SRP (CZ-58) 3.6.3 Place CZ Disch to Flume Flow Control Valve SRP (CV-4642) hand switch to OPEN.
A. Verify FIC-4642 in Manual and fully open SRP CV-4642 using the Manual Adjustment Knob.
3.6.4 Lower RI-4642 alarm setpoint until HIGH RAD SRP alarm actuates.
3.6.5 Verify from CV-4642 indicating lights that SRP CV-4642 trips closed.
3.6.6 Place CV-4642 HS to CLOSED position. SRP A. Turn Man. Adj. Knob to fully Closed SRP Position (fully counterclockwise).
3.6.7 Adjust RI-4642 setpoint to the value listed in SRP the Preliminary Report for total Circ Water flow.
3.6.8 Verify a Licensed Operator, other than SRP individual who initially set RI-4642 setpoint, has independently verified that RI-4642 setpoint is correct for total circ water flow.
3.6.9 Reset RI-4642 HIGH R4D alarm. SRP 3.7 IF RI-4642 is inoperable
- unavailable, THEN verify requirements specified in "Analysis" section of this permit for RI-4642 inoperable 5 unavailable have been performed. Otherwise N/A.
Section 3.0 Performed By Steve Pullim
PROCJWORK PLAN NO. PROCEDUREMTORK PLAN TITLE: PAGE: 101 O f I 2 2 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042-00-0 ATTACHMENT B2 Page 5 of 9 4.0 Release (Operations)
CAUTION Unauthorized discharge to Lake Dardanelle via the flume shall be avoided. I 4.1 Verify CZ Disch to Flume Flow (CV-4642) closed. SRP 4.2 Verify T-16B X-FER PP (P-47B) stopped. SRP NOTE Tag contains information to remind personnel that tank is isolated for chemistry sample.
4.3 Verify Treated Waste Monitor Tank T-16B Inlet (CZ-47B) SRP closed tagged.
4.3.1 IF tag is missing
- has been removed since tank was last sampled, THEN perform the following. Otherwise N/A.
A. Terminate this release.
B. Install tag on CZ-47B.
C. Submit new release permit to Chemistry. N/A 4.4 Verify Treated Waste Monitor Tank T-16B Outlet (CZ-48B) SRP open.
4.5 Verify Treated Waste Discharge Valve to Header from P-47A SRP (CZ-55A) closed.
4.6 Verify Treated Waste Monitor Tank T-168 Recirc Inlet SRP (CZ-54B) closed.
4.7 Open Treated Waste Discharge Valve to Header from P-478 SRP (CZ-558).
4.8 Open Treated Waste Discharge to Circ. Water Flume (CZ-58). SRP 4.9 Verify Treated Waste Monitor Pump Discharge to Clean Waste SRP Tanks (CZ-57) closed.
4.10 Verify Unit l/Unit 2 Liquid Radwaste Manifold Is01 (CZ-87) SRP closed.
4.11 Verify Suction Crossover on Treated Waste Monitor Pumps SRP (CZ-50) closed.
PROC.WORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 102 of 122 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042-00-0 ATTACHMENT B2 Page 6 of 9 4.12 IF Liquid Radwaste Process Monitor (RI-4642) is inoperable or unavailable, THEN perform the following. Otherwise N/A (ODCM App.1, L2.1.l).
4.12.1 Verify FWMT Disch to CW Flumes (DZ-25) closed. N/A 4.12.2 Verify LZ Drain Pump P-45 Discharge to Flume N/A (LZ-5) closed.
4.12.3 Person qualified as Waste Control Operator, N/A independently verify release path valve alignment prior to release (ODCM App.1, Table 2.1-1).
SRP 4.13 Notify control room of intent to begin release.
4.14 Commence T-16B release as follows:
SRP 4.14.1 Start P-47B.
4.14.2 Place CZ Disch to Flume Flow (CV-4642) hand SRP switch to OPEN.
CAUTION Use of flow rate areater than allowable by the release permit may violate ODCM limlts for release and may be NRC reportable.
II NOTE Allowable Release Flow Rate is Listed in the "Max Waste (GPM)" Column of the Preliminary Report.
4.14.3 Use C Z Disch to Flume (FIC-4642) to obtain flow rate < allowable release flow rate for total circ water flow.
Max Flow Rate from Preliminary Report ( 90 gpm) 1 . Note: F I C 4642 inoperable, cannot determine flow r a t e , procedure i s deviated, r e l e a s e can continue a s long a s flow i s estimated every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
. PROC.MIORK PLAN NO. PROCEDUREMIORK PLAN TITLE: PAGE: 103 of 122 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042000 2
ATTACHMENT B2 Page 7 of 9 4.15 WHEN release has started, perform the following:
4.15.1 Control Room Personnel shall observe Discharge -
Flow to Flume (FI-4642). Verify release flow rate is 5 allowable release flow rate for total circ water flow.
A. IF FI-4642 is inoperable,
%EN estimate
- flow rate at least once every four hours during release (ODCM App.1, Table 2.1-1). Otherwise N/A.
NOTE If a Plant Computer tabular Log (DUMP) is used instead of Process Radiation Monitoring Effluent Recorder (RR-48301, the tabular log shall contain at least points R4642, R3618 and be set at 5 5 minute intervals and cover the duration of the release.
4.15.2 Record the following data on RR-4830.
IF RR-4830 not available, ZEN
- verify Plant Computer tabular log is activated and record data on it.
A. Release start time Date B. Release permit number C. Name and number of tank being released:
"TWMT (T-16B)"
4.15.3 Notify RP that T-168 release has started and LRW disch filter F-560 should be periodically monitored for Rad levels.
4.15.4 Notify Chemistry that T-16B release has started.
r PROC.MM)RKPLAN NO. PRDCEDUREMlORK PLAN TITLE: PAGE: 104 of 122 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042-00-0 ATTACHMENT B2 Page 8 of 9 W T I U N Pumping radioactive liquid tanks empty can cause sediment in bottom of tank to be deposited in discharge piping. This can produce higher radiation areas in the vicinity of the discharge piping than previously existed.
4.16 Verify by tank level observation that only T-16B is being released.
NOTE Liquid Radwaste Disch Filter (F-560) inlet press should not exceed 25 psig.
4.16.1 Monitor F-560 during release for a rise in inlet i
pressure.
4.16.2 -
IF LRW Disch Filter (F-560) inlet press on PI-4606 exceeds 25 psig, THEN perform the following:
A. Stop P-478.
B. Place C Z Disch to Flume Flow (CV-4642) handswitch to Close.
C. Perform "Backflushing the Liquid Radwaste Discharge Filter (F-560)" section of this procedure.
D. WHEN backflush is complete, THEN recommence release at step 4.14 of this Attachment.
4.17 WHEN release is complete, THEN perform the following.
4.17.1 Verify P-47B is off and hand switch is "Green Flagged".
4.17.2 Verify discharge flow -zero gpm.
4.17.3 Notify RP that T-16B release is complete and that F-560 should be surveyed for Rad levels to determine the need to back flush F-560.
4.17.4 Back flush F-560 as necessary per RP survey.
4.18 Notify control room that release is complete.
PROCNORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 105 of 122 1104.020 CLEAN WASTE SYSTEM OPERATION CHANGE: 042-00-0 ATTACHMENT B2 Page 9 of 9 4.19 Record the following data on RR-4830.
IF RR-4830 was not available,
- record on Plant Computer tabular logsheets.
THEN A. Release stop time Date B. Release permit number 4.20 Flush clean waste to discharge flume piping as follows:
4.20.1 Close Treated Waste Discharge Valve to Header from P-47B (CZ-550) 4.20.2 Close CZ-58.
4.20.3 Align demineralized water to discharge piping by opening Condensate Flush Disch Hdr (CS-256).
4.20.4 After flushing piping for CS-256.
- 5 minutes, Close 4.21 Place CV-4642 hand switch to CLOSE and verify indicating lights show valve closed.
4.21.1 Verify FIC-4642 in manual and turn Man. Adj.
Knob to CLOSED position [fully counterclockwise) 4.22 Record final T-16B level 6 4.23 Remove tag from Treated Waste Monitor T-16B Inlet (CZ-47B).
4.24 Return release permit with all attachments to CRS/SM.
Performed by Date Approved by CRS/SM Date 4.25 Return the following to Chemistry:
This attachment Release permit Tabular logsheets, if used.
ES-301 Administrative Topics Outline Form ES-301-1 Facility: ANO-1 Date of Examination: 9-12-05 Examination Level (circle one): RO I@ Operating Test Number: 1 Type Administrative Topic Describe activity to be performed code' (see note)
Conduct of Operations Ability to apply technical specifications for a system.
NIS New adrnin JPM A1JPM-SRO-TS1 2.1.12 (Imp 4.0)
Ability to maintain primary and secondary plant Conduct of Operations NIS chemistry within allowable limits.
2.1.34 New admin JPM AIJPM-SRO-CHEMI (lmp2.9)
Equipment Control Knowledge of the process for controlling temporary N
SI changes.
2.2.11 New admin JPM A1JPM-SRO-TALT2 (Imp 3.4)
Radiation Control Ability to perform procedures to reduce excessive MIS levels of radiation and guard against personnel 2.3.10 exposure.
(Imp 3.3) Modified A1JPM-SRO-RC22 Emergency Plan Knowledge of the emergency plan, NIS New admin JPM AIJPM-SRO-EAL9.
2.4.29 (Imp 4.0)
NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrativetopics, when all 5 are required.
Type Codes & Criteria: (Cfontrol room (D)irect from bank (S 3 for ROs; S 4 for SROs)
(N)ew or (M)odified from bank (2. I (P)revious (2 1; randomly selected)
(S)imulator J
ES-301, Page 22 of 27
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TS1 Page Iof 4 UNIT: 1 REV # Q
--,. DATE:
TUOI NUMBER: A1JPM-SRO-TS1 SYSTEMIDUTY AREA: ADMINISTRATIVE TOPIC - CONDUCT OF OPERATIONS TASK: Applv technical specifications for a system.
JTA#: ANO-SRO-ADMIN-NORM-22 KA VALUE RO: 2.9 SRO: 4.0 KA
REFERENCE:
2.1.12 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: NlA SRO: X ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 30 MINUTES REFERENCE(S): Unit One Technical Specifications: 1104.036 EXAMINEE'S NAME: SSN -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THlS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THlS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist System Walkthrough" poition of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: The plant had been operatina at 100% for 100 davs. DH ourno P-34A is taaaed out to replace a leakinq seal. The monthly surveillance for DG2 has beaun to ensure it is completed within the requirements of the surveillance schedule.
TASK STANDARD, Examinee correctly recoqnizes that Tech Spec LC0 SR 3.8.1 . I 3.8.1 condition B is applicable. LC0 3.8.1 condition 8.2 declare the DH pump P-34B inoperable due to inoperable ememencv power supply. LC0 3.5.2 condition C applicable due to both DH pumps inoperable. 3.5.2 condition C is also applicable, and LC0 3.0.3 must be entered.
TASK PERFORMANCE AIDS: 1104.036: Technical Specifications
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TS1 Page 3 of 4 INITIATING CUE:
The CBOT has just performed, Supplement 2, DG2 Monthly Test, of 1104.036 through step 2.9.4, he discontinued the test per step 2.9.5, and has given you, the CRS, the supplement for review.
CRITICAL ELEMENTS (C) 4 (c) PERFORMANCE CHECKLIST STANDARD II I Review supplement. 1I Reviewed supplement
- 2. Perform step 3.2. Performed the following:
Immediately notified Shifl Manager.
Declared DG2 inoperable.
Verified a Condition Report initiated.
Initiated corrective action.
- 3. Per step 3.2, reference Tech Specs. Referenced Tech Specs
- 4. Determine applicable Tech Specs Determined the following:
and required actions. SR 3.8.1.1 LC0 3.8.1 condition B applicable
. due to inoperable DG2.
LC0 3.8.1 condition 8.2. declare the DH pump P-348 inoperable due to inoperable emergency power supply.
LC0 3.5.2 condition C applicable due to both DH pumps inoperable, LC0 3.0.3 would be entered.
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-SRO-TS1 Page 4 of 4 EXAMINEE'S COPY JPM INITIAL TASK CONDITIONS:
The plant had been operating at 100% for 100 days.
DH pump P-34A is tagged out to replace a leaking seal.
The monthly surveillance for DG2 has begun to ensure it is completed within the requirements of the surveillance schedule.
INITIATING CUE:
The CBOT has just performed, Supplement 2, DG2 Monthly Test, of 1104.036 through step 2.9.4, he discontinued the test per step 2.9.5, and has given you, the CRS, the supplement for review.
r ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLEAR ONE TITLE EMERGENCY DIESEL GENERATOR DOCUMENT NO CHANGE N O OPERATION 1104.056 042-03-0 WORK PLAN EXP DATE TC U(P DATE NIA NIA SET # SAFETY-RELATED IPTE BYES RNO BYES mN0 TEMP ALT RYES @NO When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Distractionl~nterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShiWLast Shift Peer Pressure Procedures ChangeiW Normal Job Eriefing
PROC.IWORK PLAN NO. PROCEDUREIWORKPLAN TITLE: PAGE: 104 Of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-035 SUPPLEMENT 2 Page 1 of 30 DG2 MONTHLY TEST This test demonstrates operability of DG2 and the AC, DC, and shaft-driven lube oil system; air start system; fuel oil transfer system; engine cooling system and ventilation system and satisfies SR 3.8.1.2, SR 3.8.1.3, SR 3.8.1.4, SR 3.8.1.6, SR 3 . 8 . 3 . 3 , TR 3.8.3.1, and TS 5.5.8 (AN0 IST program requirements). Reg Guide 1.97 Instrumentation channel check6 of DG instrumentation are performed in this Supplement. Instructions are provided for pre- and post-operation checks. Data is recorded to assist in tracking performance trends of the diesel and generator.
NOTE Inoperable safety-feature valves may be locked in their actuated position to maintain overall operability.
DG start location alternates with each performance of a regularly scheduled test. I 1.0 INITIAL CONDITIONS INITIALS 1.1 Ci- ck the purpose of this test:
- Regularly scheduled monthly test (local, remote start) circle one
-8. Regularly scheduled quarterly test (includes P-169/DG vibration data). (!.ocal, remote start) circle one
-C. Operability test foliowing significant maintenance (describe maintenance performed in section 4.0).
-D. Two hour loaded run following a series of Supplement 12 Operability tests.
.- E. Other (describe in section 4.0).
1.2 Service water loop II in service 1.3 -
IF this rest is returning DG2 to operable condition, E N verify DG2 aligned for emergency standby per Attachment D.
1.4 A stopwatch shall be used to clock DG to verify unit is available to carry load within 15 seconds.
M&TE No. bEl, 07g- cal Due Date - -
il-C?-PS 1.4.1 Record stopwatch M&TE number in section 3.0.
PROC.MTORK PLAN NO. PROCEOUREMTORK P U N TITLE: PAGE: 105 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 2 of 30 1.5 Contact Dispatcher with the following information exchange:
Notify Dispatcher that DG surveillance will be conducted.
. Verify no off-site grid disturbance is expected, such as a severe electrical storm in the area.
Request dispatcher notify AN0 Unit 1 if any disturbances develop.
1.6 IF this is a regularly scheduled monthly or quarterly test, /P/
notify Chemistry to prepare to sample fuel oil, lube oil, and cooling water.
1.7 Obtain cylinder drain cock tool, engine jacking mechanism, -y;.r and hearing protection.
1.8 Review the following limits and precautions: &c!I.c.
Diesel rJn time unloaded or at low load (<75%3 should be minimized in order to prevent carbon fouling (improper combustion) and excessive turbocharger gear train wear.
Do not attempt diesel generator restarts until engine has stopped I0 RPM) .
Governor booster pump tubing should be inspected for leaks during diesel run to prevent loss of governor control oil pressure.
During periods of known off-site electrical grid disturbances, neither diesel should we paralleled with the grid.
Do not tie both EDGs to the grid simultaneously when both EDGe are in operation. One DG shall be dedicated only to its ES bus. Otherwise a single grid electrical fault may cause a loss of both emergency diesel generators.
. A delay in opening output breaker at 100 KW when unloading a diesel may result in a motoring trip A delay in loading a diesel after closing the output breaker may result in a motoring trip.
Actions such as resetting, changing control switch positions, reconfiguring components, or attempting diesel restart after failure can cause loss of data useful in diagnosing problems and should be avoided if not an emergency.
PROC-MYORKPLAN NO. PROCEDUREIWORK PLAN TITLE: PAGE: 106 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMrnT 2 Page 3 of 30 Adjusting either Unit 1 or Unit 2 Main Generator reactive loading may result in significant changes in EDG reactive loading while the diesel generator is paralleled to the grid.
Maximum ambient temp for diesel operation is 122°F.
Verify ventilation fans operate to maintain ambient temp
< maximum allowed.
r Maximum engine outlet water temperature is 205°F.
Minimum oil pressure is 26 psig when diesel is operating at 900 RPM.
1.9 Verify SERV WTR to 002 CLRS (CV-3807! is closed. 2.L 1.10 Portable vibrometer available. -4r' 2.0 TEST METHOD 2.1 -IF during the performance of this supplement it is desired to monitor DG2 crankcase pressure, THEN
.- perform the following:
2.1.1 Open K-48 Crankcase Pressure PI-52448 Isolation (FO-5244B).
2.1.2 Monitor PI-5244B 2.1.3 Close F0-52448 2.2 -IF during the performance of this supplement it is desired to nonitor m 2 air box pressure, THEN perform the following:
2.2.1 Open K-4B Air Box Pressure PI-52458 Isolatio31 (FO-5245B1.
2.2.2 Monitor PI-52458 2.2.3 Close FO-5245B
.PR0C.NVORK PLAN NO. PROCEDUREMTORKPLAN TITLE: PAGE: 107 O f 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 4 of 30 2.3 Lubrication System Testing 2.3.1 Check engine lube oil level between '/, and 1" ..&L above dipstick full mark with engine stopped.
A. g oil level. is low, .Mi%.
THEM submit WR/WO for oil addition.
- 8. IF oil level is below LOW mark, do run diesel untii oil is added.
- M%
- 1) Stop the test AND notify the Shift Manager.
2.3.2 Verify DG2 AC Lube Oil Soak Back Pump (P-10683) 4rg running.
A. Record lube oil pressure at DGZ - r*t Turbocharger BRG Oil PRESS (11-5271)on OG2 engine control panel ClO8.
26 psis 2.3.3 Turn DG2 AC Lube Oil Soak Back Pump (P-10683) hand switch to OPF.
fnt A. Check 062 DC Lube Oil Soak Back Pump JP-106B1)starts.
B. Acknowledge SOAK BACK PP (P-106B3) OPF (K1613 on C 5 6 7 ) annunciator.
C. Record lube oil pressure to turbo bearings at PI-5271.
A d b
'4" Z 2.3.4 Place P-106B3 hand switch to ON.
A. Check P-106B3 starts.
B. Check P-10681 stops.
C. Record lube oil pressure to turbo bearings at PI-5271.
-"M
&b psig
PROC.MIORK PLAN NO. PROCERUROWORK PLAN TITLE: PAGE: 108 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-031)
SUPPLEMENT 2 Page 5 of 30 2.3.5 Verify nG2 AC Lube Oil Soak Back hlmp (P-10682) dx.-
running.
I NOTE Pump discharge pressure must be 730 psig to circulate oil through 30# spring loaded check valve. DGZ AC Lube Oil Soak Back PumD P-10602 Disch CK A. Record discharge pressure at DG2 AC labe Oil Soak Back Pump P-10692 DISCH PRESS B. IF P-10682 discharge pressure is c30 psig, 23-
%EN stop test and notify Shift Manager.
2.3.6 Clear Soak Rack Pump alarms. S L NOTE Technical Specification SR 3.8.3.3 requires verifying each DC air start receiver pressure is 2 175 psig on a 31 day frequency. This surveillance requirement ensures that without the aid of the starting air compressor, sufficient air start capacity for DG is available. The required receiver consists of one bank of two tanks, The following step checks both banks, although only one bank is required.
2.4 Air Start Receiver Test 2.4.1 'Jerify the DGZ Starting Air Corrpressor Receiver pressure is s 175 psig per the following li.8' pressure indicators: (circle inszruinents used here and in Section 3.0)
PROC.MIORK PIAN NO. PROCEDUREWORK PLAN TITLE: PAQE: 709 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 6 of 30 NOTE Governor oil level is intended to be maintained between the high and low marks when che EDG is in operation.
Governor should operate normally with high oil level.
Governor oil level will rise when the EDC is shutdown.
2.5 Control oil Check 2.5.1 Check governor oil level sightglass - 1/2 full In, A. P low, submit WR/WO for oil addition
- 0. gempty, THEN do NOT run diesel until oil is added.
C. - -
IF governor sightglass, oil level is above the THEN submit WR/WO for oil removal.
2.6 Cooling Water Check 2.6.1 Check OG2 Cooling Water Expansion Tank (T-78Bl water level within band for engine stopped.
A. 2 below lower limit, THEN add DI water uxtil -I/,
in the "Engine Stopped" band.
band is reached 2.7 Verify no compression cylinder inleakage as follows:
2.7.1 IF any of the following conditions exist, N/A steps 2.7.2 through 2.7.11. Otherwise N/A this step and GO TO step 2 . 7 . 2 .
A. iX1 inoperable B. Any Tech Spec required odd train ES component inoperable
PROC.NVORK PLAPl NO. PROCEDURElWORKPLAN TITLE: PAGE: 1 1 0 0 f 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 7 of 30 CAUTION Placing engine control selector switch in MAINT will prevent diesel start, rendering DG2 inoperable. I NOTE If DG2 becomes inoperable for ?1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, then the following should be performed:
E55/56 should be aligned to load center associated with operable diesel.
OP and STBY HPI pumps shou1.d be aligned to the operable EDG.
2.7.2 Perform the following:
A. IP i(CS above Mode 5, -
s~f' THEN enter TS 3.8.1 Condition B.
Time 0933 Date 3 - t z . G ~
NOTE Ucit 2 requires 30th VSF-9 and 2VSF-9 to maintain auto-start capability in Modes 1-4, which also requires operability of both normal and emergency power supplies. Thus if VSF-9 is powered from AND1 and B55/56 are aligned to an inoperable E X , AN02 must declare VSF-9 inoperable.
B. Notify Unit 2 that DG2 is inoperable. in/
- 1. B55/B56 are aligned to 86, %
THEN inform Unit 2 that VSF-9 is inoperable for Unit 2.
C. DGZ inoperability will exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, perform the following:
Complete 1107.001, Sup 10, Verification of Two Offsite Circuit Power Sources
- If desired, align B55/56 to load center associated with operable EDG If desired, align OP and STBY HPI pumps to bus associated with operable EDG
PROC.MORK PLAN NO. PROCEDUREMORK PLAN TITLE: PAGE: 11%of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 04253-0 SUPPLEMENT 2 Page 8 of 30 2.7.3 Place Engine Control selector switch an Cl08 in MAINT.
-S Per.
A. Xecord time HS placed in MAINT. -XbJ 0 % ~
B. IF power is iost to bus A4 during performance of this section of the urocedure .
THEN perfbrm the following:
- 1. Verify MCC B55 and 8 5 6 powered from bus B5.
- 2. Remove engine jacking mechanism
- 3. Close a11 cylinder drain cocks snug1.y using the cylinder drain cock tool.
- 4. Return Engine Control selector switch to REMOTE.
2.7.4 Open all cylinder drain cocks -3 tunis. &
jacket or fuel system failure.
2.7.5 CAUTION Water or oil exiting ports prior to engine rollover indicates gross water Observe cylinder drain cock ports for water or oil.
I 2.7.6 -
IF drainage is observed, THEN perform the following:
A. Do NOT roll over diesel as engine damage WILL occur.
A 1
B. Mark affected cylinderls) on vibration reading data sheet diesel illustration. 4-C.
- 1. Record type of Liquid in section Discontinue this test AND notify Shift 4.0.
-I-Manager that 0 0 2 is inoperable.
PROC.hVORK PLAN MO. PROCEDUREWORK PLAN TITLE: PAGE: 112 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 9 of 30 2.7.7 Roll over diesel by installing engine jacking mechanism and manually jacking engine over at fAr least one full turn.
2.7.8 Remove engine jacking mechanism. -Jq 2.7.9 Observe cylinder drain cock ports for water or -
-."#I oil.
2.7.10 IF drainage is observed,
%EN perform the following:
A. Mark affected cylinder(s) on vibration &@--
reading data sheet diesel illustration.
B.
- 1. Record type of liquid in seccion 4 . 0 .
Discontinue this teat AND notify Shift
- b Manager that E 2 is inoperable.
2.7.11 Close all cyf inder drain cocks snugly using the cylinder drain cocR tool.
/"\P
PROC.iWORK PLAN NO. PROCEUURUWORK PLAN TITLE: PAGE: 1130f214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-034 k
SUPPLEMENT 2 Page 10 of 30 2.8 Verification of r,ocaI Start Capability 2.8.1 Record DG2 Engine Total HRS (C1OB): *bdZ.$ hrs. -jB(
NOTE If other than regularly scheduled test, start location is optional.
2.8.2 From "Initial Conditions" section of this supplement, note which starting station is to be used for this test, local or remote.
A. IF THEN remote, place Engine Control Selector switch
/*/
on C108 in RBMOTE.
- 8. F
[
I Local, rvqA TKEN place Engine Control Selector switch on ClO8 in LOCAL.
C. Record time HS removed from MAINT. -
6~'
o?JI NOTE Placing Engine Control Selector switch in LOCAL restores autostart capability and operability.
D. IF applicable, ZEN exit all TS Conditions entered for a
perfoririance of this test.
Time 0 ' t f L Date 4 -I%-*?
E. Notify Unit 2 that M2 is operable.
Otherwise N/A, if proving operability after maintenance.
2.8.3 -
IF LOCAL is selected, THEN continue with step 2.8.4 2.8.4 IF REMOTE is selected, ZEN W TO step 2.9 and N/A steps 2.8.5 through fnf 2.8.15.
2.8.5 Station operators to observe starter rnotor(si used for diesel start to determine which starter
-Ma functioned AND verify presence of oil in starter exhaust.
PROC.MIORK PLAN NO. PROCEDUREMIORK PLAN TITLE: PAGE: 114 O f 2 1 4 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042434 I
SUPPLEMENT 2 Page 11 of 30 NOTE Be prepared to clock elapsed time from start signal until voltage exceeds i750 volts.
2.8.6 Perform local start of diesel aa follows:
A. Start, or verify started, Diesel Generator Room Exhaust Fans AND verify dampers open on C19 or locally.
- 1. Verify VEF-24C running. -PIA 2.
3.
4.
5.
Check Damper TV-7902A Verify VEF-24D running.
open.
Check Damper TV-7902B open.
Record verification in section 3.0 E
I
--I-
+
B. Verify volts selector switch for DG2 AC Voltage meter Lon E211 NOT in OFF.
C. Simultaneously depress START pushbutton on ClOB AND star; the stopwatch.
D. m2 voltage exceeds 3750 volts, THEN stop the watch.
2.8.7 Record the following in section 3.0:
A. Time elapsed from operation of start switch until voltage exceeded 3750 volts.
B. stroking of starter bank used: (Check one)
SV-5237, CV-5237 and FO-164(north bankl-we-,
OI' SV-5239, CV-5239 and FO-163(south bank)- 9..
2.8.8 Record Time/Date of DG2 start.
PROC.IWORK PLAN NO. PROCEDUREWORK PUW TITLE: PAGE: 1150f214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CRANGe: 042-03-0 SUPPLEMENT 2 Page 12 of 30 2.8.9 Check presence of oil in exhaust of starter kYL.
used.
2.8.10 A. no indication of oil,
- submit WR/WO to refill oiler and THEN continue surveillance.
Open DG2 Air Box Trap ST-68 Bypass (FO-1066Di t
+
AND check for water in effluent.
A. Close PO-1066D.
- 5. IF there is water i n effluent, THEN submit WRIWO and continue surveillance.
2.8.11 Stop diesel (pushbutton on C1OB) 2.8.12 Record TimelDate of DC2 stop.
2.8.13 -
IF time to exceed 3750 volts is greater than 15 seconds,
-+
THEN perform the following.
A. Inform the Shift Manager.
B. Declare DG2 inoperable.
I 2.8.14 C. Discontinue the test.
Place Engine Control selector switch Ln REMOTE.
4 2
NWLrj Starting diesel generator from each bank (north and south) satisfies quarterly ASME stroking requirements of Emergency Diesel Generator Air Relay Valves to K-4B (CV-5237 CV-S239). Failure of starter to engage does not render diesel inoperable provided opposite starter bank maintains required 15 ~econdStart time.
2.8.15 Station an operator at the diesel to verify opposite starter bank is used on second (control a
room) start AND verify presence of oil i n starter exhaust.
2.9 Verification of Remote Start Capability 2.9.1 Reset or acknowledge all alarm8 on local alarm I . ,
panel K1613.
2.9.2 Record initial DG2 Watt-Hour Meter (C20j reading: '"d
PROC.NIORK PLAN NO. PROCEDUREWORK PLAN ~ T L E PAGE: 116of214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHIINGE: 042-03.0 SUPPLEMENT 2 Page 13 of 30 i I NVlCl Be prepared to ciock elapsed time from start signal until voltage exceeds 3750 volts.
2.9.3 Perfom remote start of diesel as follows:
A. Start, or verify started. Diesel Generator Room Exhaust Fans AND verify dampers open on C19 or locally.
- 1. Verify VEP-24C running.
- 2. Check damper 7%-7902A open. -/r{
- 3. Verify VEF-24D running. -
Jfi f
- 4. Check damper TV-7902B open. / n ,
- 5. Record verification in section 3.0. JAf B. Verify DG2 Volts Select switch NOT in OFF J l r ?'
(C10).
C. Simultsneousiy depress STiiXT pushbutton A?JD A Start the stopwatch.
D. -WUi 062 voltage exceeds 3750 volts. &
THEN stop the watch.
2.9.4 Record time elapsed from operation of start switch unt;il voltage exceeded 3750 volts on panel C10 in section 3.0.
2.9.5 IF time is greater than 15 seconds,
?%EN perform the following.
A. Inform Shift Manager.
R. Declare DG2 inoperable
'C. Discontinue test.
2.9.6 Verify SERV WTR to 302 CLRS ( C V - 3 8 0 7 ) is open and record verification in section 3.0.
2.9.7 Record Time/Date of DG2 start. -
2.9.8 Gather the following data and record parameters per log OPS-Al5b:
Each DG2 Voltage Phase (1-2, 2-3, 3-1)
DG2 Fiald Amps Voltage Regulator Controi current
PROC.IWORK PL#N NO. PROCEDURElWORK PLAN TITLE: PAGE: 117 0f 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 14 of 30 2.iO ParalLel of diesel generator with grid:
C!AUTION With the DG paralleled to the grid, grid disturbance could cause damage to the DG.
2.10.1 IF DC2 is paralleled to the grid,
& the reactor trips.
i)!! offsite power is lost,
-THEN follow "DG operation when paralleled to the grid and the reactor trips or offsite power is lost" section of this procedure.
2.10.2 Turn Synchronize switch ON for DG2 Output Breaker (A-408).
2.10.3 Verify smooth voltage and frequency control by exercising controls on CiO.
-NOTE ES Bus A4 voltage (running) and DG2 voltage (incoming) can be compared by using SPDS. Comparison points are:
ElA4 (A4 Voltage)
EiDG2 (DG2 Voltage1 2.10.4 Adjust DC2 voltage regulator to match RUNNING P and INCOMING voltages (DG2 is INCOMING).
2.10.5 Adjust 1x22 governor control until frequency is
-60 Hz with synchroscope rotating slowly in FAST direction.
r PROC.IWORK PLAN NO. PRWEDUREIWORKPLAN T I R E ! PAGE: I18 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-036 SUPPLEMENT 2 Page 15 of 30 CAUTION A delay in loading diesel after closing output breaker may result in a motoring trip.
In parallel operation, maximum allowed reactive load is 1200 XVAR out and 500 W A R in at full load.
Maximum current is 450 amps. Do not exceed except in emergency.
NOTE If synchroscope is rotating too fast, sync-check relay will prevent breaker from closing.
Ij . Gradual and uniform load changes minimize engine wear and internal stresses. A 1 0 0 % load change requires -90 sec.
If available, SPDS point JlDG2 or EDS Display should be used for DG load.
I1 Momentary transients above or below the required loading value due to variations in load do not invalidate the test.
2.10.6 A s synchroscope approaches 12 o'clock
( - 5 min 'til), close breaker A - 4 0 8 .
position -
A. Immediately begin gradually raising load to Eull load (2750 KWI using DG2 governor control. Take -90 seconds.
B. Maintain - 0 kilovars using DGZ voltage regulator.
2.10.7 Record Time/Date when DG2 output is between 2625 -
and 2750 KW.
2.10.8 Turn Synchronize switch OFF. -
2.11 Perform the following as applicable:
2.11.1 IF this is a regularly scheduled monthly or quarterly test, THEN request Chemistry Department to sample Emergency Diesel Fuel Tank T-57B per Sampling Diesel Fuel (1618.010) and cooling water per Sampling Emergency Diesel Generator's Caoling Water ( 1 6 1 8 . 0 1 4 ) .
Name of Chemist Informed
PROC.IWORK PLAN NO. PROCEDUReNVORKPLAN TIRE: PAGE: 1190f 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0
- 1 SUPPLEMENT 2 Page 1 6 of 30 2.11.2 -
IF t h i s is a l o c a l s t a r t t e s t ,
THEN record s t r o k i n g of opposite DG2 s t a r t e r bank, i n s e c t i o n 3 . 0 .
2.11.3 -
IF t h i s i s a local s t a r t t e s t ,
THEN check f o r presence of o i l i n exhaust of s t a r t e r used.
A. g no i n d i c a t i o n of o i l ,
THEN submit IVR/WO t o r e f i l l continue s u m e i l l a n c e .
o i l e r and 2.11.4 V e r i f y c y l i n d e r d r a i n cock t o o l and engine jacking mechanism returned t o a p p r o p r i a t e storage location.
2.11.5 I F requested by SYE, EEN open (FO-1066D).
DG2 A i r Box Trap ST-68 Bypass A. Close PO-1066D.
2.12 WHEN DG2 has operated f o r 1 5 minutes between 2625 and 2750 KW, T K N perform t h e following:
2.12.1 t h i s i s a r e g u l a r l y scheduled q u a r t e r l y t e s t a s noted i n I n i t i a l Conditions, THEN n o t i f y v i b r a t i o n d a t a c o l l e c t i o n personnel t o t a k e P-16B v i b r a t i o n d a t a when t h e pump i s running. Otherwise N/A t h i s s t e p and P-169 vibration data i n section 3.0.
1 Fuel o i l Day Tank T-30a. DO not CAUTION Running DGZ Fuel T r a n s f e r Pump (P-16Bj i n HAND can cause overflow of DG2 allow tank t o f i l l ,250 g a l l o n s .
if I Completion of t h e following s t e p s s a t i s f r e s q u a r t e r l y ASME s t r o k i n g requirements of P-168 Outlet Check Valve(F0-8B).
i I 35 minutes e n s u r e s t h e EDG has consumed s u f f i c i e n t f u e l o i l t o reqiiire Fuel Transfer Pump o p e r a t i o n . I 2.12.2 Monitor day tank l e v e l t o determine i f DG2 Fuel T r a n s f e r P!mp I?-16Bl is running.
A. IFP-16BisErunning.
a t l e a s t 35 minutes of EDG o p e r a t i o n has e l a p s e d ,
THEN v e r i f y T-30B S 220 g a l . and s t a r t P-16B i n HAND.
PROC lWORK PLAN NO PROCEDUREIWORK PLAN TIRE PAGE 120 of 2 1 4 2 104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE 542-03-0 SUPPLEMENT 2 Page 2.12.3 Monitor day tank level until level rises by at Least l o gallons.
A. Record ability of P-16B to raise level in section 3.0.
U. Record T-308 level here and in section 3.0.
gal (LG-5237) 2.12.4 IF P-16B is in HAND,
%EN return P-16U to AUTO 2.13 DaKa gathering afcer 30 minutes between 2625 and 2750 KW:
2.13.1 Record DGZ parameters per DG2 Logsheet IOPS-AlSb).
2.13.2 Record local 002 Emergency Diesel Fuel Tank T-578 Level (PDIS-52121 (in fuel vault).
inches.
2.13.3 IF tank level is c148".
"."" initiate corrective actions 2.13.4 IF this is a regularly scheduled quarterly test, stroke DGZ Emerg Diesel Fuel Tank T-57B crossover (FO-1OB) as follows:
A. Stroke FO-1OB open, then closed
- 1. Record results in section 3.0 2.13.5 IF this is a regularly scheduled quarterly test, THEN verify vibrometer readings taken per data sheet of this supplement.
2.13.6 Check SPDS EDS VTAL screen and verify diesel generator parameters display approximately the same value as C10 instrumentation for:
DG2 Power DG2 Voltage DG2 Frequency A. Record in section 3.0.
PROC.NYORU PLAN NO. PROCEDURUWORU PLAN TITLE: PAGE: 121 Of214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 18 of 30 The fuel oil filter "bypass" sight glass (farthest from the engine) 1 should be empty in normal operazion, if fuel oil is in this sight glans, the fuel oil filter should be changed.
The "return fuel" sight glass (nearer the engine) passes returning fuel from the injectors to the day tank. This sight glass should normally be full. Air bubbles in this sight glass with the fuel priming pump running and the engine stopped indicates air entering the suction of the pump.
Bubbles appearing only when engine is running indicates leaky valves in file1 injectors. Little or no fuel in the sight glass indicates insufficient Euel to the engine.
2.13.7 Check duplex fuel oil filter sight glasses. -
A. Submit a WR/WO for repairs, as necessary, and continue surveillance.
2.14 Data gathering after one hour between 2625 and 2750 KW:
2.14.1 Record DG2 parameters per log OPS-A15b. -
2.14.2 Contact Chemistry and verify cooling water corrosion inhibitor concentration in-spec.
NOTE The following values are given to help determine when diesel temperatures have stabilized, and are not intended to limit operation:
Scavenging Pump Disc. Temp. - 190°F - 135°F Water Pump Suction Temp. - 155-F - 160°F Water Leaving Engine Temp. - 16S°F - 175OF 2.15 WHEN one hour between 2625 and 2750 KW has elapsed
@ . engine water and oil temperatures have stabilized, THEN perform the following:
2.15.1 this is a test following a series of Supplement 12 Operability Teets, THEN continue full load operation for a total time of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
2.15.2 I F this test is to prove operability foilowing siqnificant maintenance.
OR requested by System Engineering, perform extended run as follows:
A. Raise load between 2730 and 2860 KW using DG2 governor control.
PROC.IWORK PLAN NO. PROCEDURWORK PLAN TRLE: PAGE 122 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-034 SUPPLEMENT 2 Page 19 of 30 B. Maintain -0 kilovars using DGZ voltage regulator.
C. Record Time/Date when DG2 output is between 2730 and 2860 KW:
Time/Date - /
D Record initial time between 2625 and 2750 KW in Section 3.0.
E. Continue taking hourly DG logs per DGZ togsheet (OPS-A15b1 F. ffi2 has operated for two hours between 2730 and 2860 KW, THEN reduce load between 2625 and 2750 KW.
- 1. Record Time/Date / -
- 2. Record run time between 2730 and 2860 Kw in section 3.0.
NOTE additional run time will be determined by System Engineering.
G. additional run time between 2625 and 2750 KW is requested by System Engineering, THEN maintain load between 2625 and 2750 KW until requested duration has elapsed.
2.15.3 Relsove diesel generator from parallel operation as follows:
A, Record Time/Date at which load reduction is commenced.
Time/Date -/
CAUTION A delay in opening output breaker at 100 Kw when unloading diesel may result in a motoring trip.
=
Gradual and uniform load changes minimize engine wear and internal stresses.
A 100% load change requires -90 sec.
B. Gradually unload DGZ to -100 KW using DG2 governor control whiLe minimizing kilovars using DG2 voltage regulator. Take -90 seconds.
PROC.NUORK PLAN NO. PROCEDUREMtORK PLAN TITLE: PAGE: 123 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 20 of 30 C. Open DGZ Output Breaker (A-408). -
D. Record Time/Date A-408 Opened: -
E. F additional run time per System -
- request was ~erformed.
Enaineerincl's THEN record the additional runtime between 2625 and 2750 KW in section 3.0.
NOTE Total runti.me between 2625 and 2750 KW is as follows:
If additional runtime was performed, the total runtime is the initial time between 2625 and 2750 KW added to any additional runtime between 2625 and I
2750 KW, OR If no additional runtime was performed, the total runtime is the difference in time from when the EDG is between 2625 and 2750 KW and the time at which load reduction began.
F. Record E N initial run time as follows: -
IF extended rim was performed,
.THEN
- record total time DG2 between 2625 and 2750 KW in section 3.0.
-IP extended run was NOT performed, TEEN record initial time DG2 between 2625 and 2750 KW in section 3.0.
2.15.4 Stop diesel as follows:
A. Adjust frequency to 60 HZ using DG2 governor control.
- 8. Adjust voltage to 4160 volts using DG2 voltage regulator.
C. DG2 has run for 17-minutes unloaded, depress STOP pushbutton.
D. Record Time/Date W 2 stopped. -
2.15.5 Complete CG Start/Load-Rim Information Sheet (Form ll04.036Al .
' PROC.FNORK PLAN NO. PROCEDURWWORK PLAN TITLE: PAGE. 124 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-035 SUPPLEMENT 2 Page 21 of 30 NOTE The following Functional Capability Test (Optional) is performed at the request of System Engineering. When required, the DG must be started within 5 minutes. If not pertormed, NIA subsection 2.16 and GO TO 2.17.
2.16 Functional Capability Test (Optional) 2.16.1 Time starting of DG2 from controi room as follows:
A. Simultaneously depress DGZ START pushbutton -
(C101 and start the stopwatch.
B. Record time elapsed from operation of start switch until voltage exceeds 3750 volts in section 3.0, Functional Capability Test Table.
2.16.2 Parailel of diesel as follows:
ES Bus A4 voltage (running) and DGZ voltage (incoming1 can be compared by using SPDS. Comparison points are:
ElA4 (A4 Voltage)
EIDG2 (DG2 Voltage)
A. Inform dispatcher that diesel generator is -
ready for loading.
- 3. Turn Synchronize switch ON for DG2 output Breaker ( A - 4 0 8 ) .
C. Verify voltage and frequency control by exercising controls on C10.
D. Adjust DG2 voltage regulator to match -
RUNNING and INCOMING voltages.
E. Adjust DG2 goverilor control until frequency is -60 HZ with synchroscope rotating slowly in FAST direction.
PROC.NIORK PLAN NO.
1104.036 / PROCEDURUWORK PLAN TITLE:
EMERGENCY DIESEL GENERATOR OPERATION PAGE:
CHANGE:
1 2 5 Of 214 042-03-0 SUPPLEMENT 2 Page 22 of 30 CAUTION A delay in loading diesel after closing output breaker may result in a motoring trip.
. NOTE If synchroscope ia rotating too fast, sync-check relay will prevent breaker from closing.
Prepare to clock diesel loading. Full load will be applied within 30 seconds of closing breaker.
F. As synchroscope approaches 1 2 o'clock -
position (-5 min t i , simuLtaneously close breaker A-408 AND start the stopwatch. Using DGZ governor control.
raise load to 2750 KW in c30 seconds.
G. W E N D 0 2 load is 22750 KW, THEN stop the stopwatch.
II. Record time elapsed from when output breaker closed to full load in section 3 . 0 ,
Functional Capability Test Tabie.
I, Turn Synchronize switch OFF. -
2.16.3 WHEN DG2 has operated for 1 5 minutes at 2625 to 2750 KW,
-THEN remove DG2 from parallel operation as fo1lows :
CAUTION A delay in opening output breaker at 100 KW when unloading diesel may result in a motoring trip.
NOTE Gradual and uniform load changes minimize engine wear and internal stresses.
A 100% load change requires -90 sec.
A. Gradually unload DG2 to -100 KW using DG2 -
governor control while minimizing kilovars using DG2 voltage regulator. Take -90 seconds.
B. Open DG1 Output Breaker (A-408) . -
PROC.NVORK PLAN NO. PROCEDUREWORK PU\M TITLE: PAGE: 126 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION C~ANGE: 042-03-0 SUPPLEMENT 2 Page 23 of 30 2.16.4 stop diesel as follows:
A. Adjust frequency to 60 WZ using DG2 governor control.
B. Adjust voltage to 4160 volts using DG2 voltage regulator.
C. Record DG2 Watt-Hour meter reading -
KWH D.
?.HEN DG2 has run for 17-minutes unloaded, depress DGZ STOP pushbutton.
2.16.5 Complete DG Start/toad-Run Informaeion Sheet (Form li04.036A).
2.17 Restoration 2.17.1 Record DG2 ENGINE TOTAL HRS iC1O.S): hrs.
2.17.2 Record DG2 Watt-hour meter reading IC20): -
KWH.
2.17.3 Verify associated critical and non-critical alarms ciear:
ED62 CRITICAL TROUBLE lK01-C41 EDG2 NON-CRITICAL TROUBLE (K01-D4) 2.17.4 m N one of the following sets of conditions are met, Ambient temperature is 540.F 9 diesel has been stopped for at least 5 min~tes Ambient temperature is s40'F AND diesel has been stopped for at least 20 minutes AND IF conditions allow, THEN return EDG Ventilation to AUTO as follows:
A. Verify VEP-24C handswitch to AUTO. -
B. Verify VEF-24D handswitch to AUTO. -
C. Verify that at least one of the following cycles off in AUTO:
2.17.5 WHEN D62 has been stopped for at least 20 minutes, THEN close SERV WTR to DG2 CLRS (cv-3ao71.
PROC.MORK PLAN NO. PROCEDUREMORK PLANTITLE: PAGE: 127 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 24 of 30 2.18 Verify the following valves closed:
K-48 Crankcase Pressure PI-52448 ISOL (PO-5244B) -
K-48 Air Box Pressure PI-52458 ISOL (30-5245B) -
2.1.9 IF this is a regularly scheduled monthly or quarterly test.
THEN notify chemists to obtain following samples.
DG2 Fuel Oil Day Tank T-30B per 1618.028.
DG2 lube oil sample per 1.618.039 2.20 Verify vibrometer readings recorded in section 3.0 as -
required.
2.21 Record AND review required data in Trend Spreadsheet Recorded and reviewed by (SE/SRO) Date 2.21.1 IF available, -
-%EN attach copies of graphs.
PROC WORK PLAN NO. PROCEDUREIWORK PLAN TITLE: PAGE: 128 0f 2 14 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLWENT 2 Page 25 o f 30 3.0 ACCEPTANCE CRITERIA 3.1 Record values o b s e r v e d d u r i n g DGZ t e s t i n g and compare w i t h
" L i m i t i n g Range For O p e r a b i l i t y . t r -
-.\-
DG2 remote
PROC.WORK PLAN NO. PROCEDURUWORK PLAN TIRE: PAGE: 1300f 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 27 of 30 3.2 IF "NO" is circled in the right hand column, -
EN perform the following:
Immediately notify the Shift Manager, Declare DG2 or component inoperable, verify a Condition Report initiated, Initiate corrective action.
Reference Tech Specs for applicable Conditions and Required Actions. It is not necessary to write a Condition Report for a failure which is already specifically addressed by an open CR, or for a fan out of service for planned maintenance.
3.3 -
IF any measured value does not fall within "Acceptable Normal Range",
THEN initiate corrective action.
(1) If "NO" is circled, declare that component only inoperabie.
(2) If remote start only N/A.
(31 N/A unless test was to prove operability following significant maintenance requested by System Engineering.
Performed by -Operator Date/Time ? ~ ! I / Q </*
Performed by Operator Date/Time Performed by Operator Date/Time
PROC.WORK PLAN NO. PROCEDUREWORK PLAN TRLE: PAGE: 131 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042436 SUPPLEMENT 2 Pase 28 of ?n 1 / ' 4' horizontal '3 6 5 horizontal.
I3 horizontal 8 9 12 11
, 10 horizontal horizontal POINT VELOCITY POINT VELOCITY POINT VELOCITY
_ NO. (IN/SEC.) NO. (IN/SEC.) NO. (IN/SEC.)
1 5 9 13 2 6 10 14 3 7 11 15 4 8 12 16 Emergency Diesel # Data Collected By -- - Date Vibrometer M&TE # Calibration Due Date
r PROC.NORK PLAN NO. PROCEOURUYVORK PLAN TITLE: PAGE: 1 3 2 O f 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CHANGE: 042-03-0 SUPPLEMENT 2 Page 29 of 3 0 P-16B PUMP VIERATXON HORIZONTAL VERTICAL Horizontal Vertical Data Collected BY Date Vibrometer M&TE #
Calibration Due Date old vibroneter probe tip firmly against the survey point marker, perpendicular to the surface. Locations of markers are depicted above.
PROC.MIORK PLAW NO. PROCEDUREMIORK PLAN TITLE: PAGE: 133 of 214 1104.036 EMERGENCY DIESEL GENERATOR OPERATION CMANoE: 042-039 SUPPLMENT 2 Page 3 0 of 30 4.0 SHIP1' MANAGER RI?VIEW RM) ANALYSIS (circle on^
4.1 Do all measured values recorded in the Acceptance Criteria section f a l l within the specified LIMITING W E FOR OPERABILITY? YES NO 4.2 Do all measured values recorded in the Acceptance Criteria section fall within the ACCEPTAaLE NORMAL RANGE? YES NO 4.2.1. -
I F "NO",
TWEN initiate corrective action and raise test frequency to once per 6 weeks m t = i resolved satisfactorily.
4.3 IF answer to either 4.1 or 4.2 is "NO',
-THEN describe acrion taken below.
4.4 Has this equipment been proven operable per the ACCEPTANCE CRITERIA? YES NO 4.5 Have all the administrative requirements of this test been satisfied ( i . e . . ali initial blocks initialed or N/A'd, a11 data entered, cal due dates listed, applicable signature spaces signed, etc.1 ? YES NO SHIFT MANAGER -- DATE
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-CHEMI Page 1 of 4 UNIT: 1 REV # &.-- DATE:
TUOI NUMBER: A1JPM-SRO-CHEMI SYSTEMIDUTY AREA: ADMINISTRATIVE TOPIC -CONDUCT OF OPERATIONS TASK: Respond to secondary chemist^ parameter out of specification JTA#: ANO-SM-ADMIN-NORM-165 UA VALUE RO: 2.3 SRO: 2.9 UA
REFERENCE:
2.1.34 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: N/A SRO: X ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1000.042 Steam Generator Water Chemistry Monitorina Unit One EXAMINEE'S NAME: SSN -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-SRO-CHEMI Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: The ~ l a nhas t been operatinq at 100% for 215 davs. The shift chemist has iust arrived in your office and has qiven vou, the Shift Manaaer, form 1000.042A to review.
TASK STANDARD: Examinee correctlv recoanizes that the threshold for Action Level 3 has been exceeded and the Dlant should be shutdown within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
TASK PERFORMANCE AIDS: 1000.042
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-SRO-CHEMI Page 3 of 4 INITIATING CUE:
As Shifl Manager, review the 1000.042A form for out of specification Feedwater chlorides.
CRITICAL ELEMENTS (C) 3
- 1. Compare results of confirmatory Requested readings of continuous analyses to readings from monitors to compare with lab continuous monitors. analyses results on 1000.042A.
I I I NOTE Inform lrainee that Chemistry suspects a bad polisher to be the source of the chlorides. I I I I I
- 2. Identify and isolate sources of impurity ingress.
Inquired as to results of searches for source of chloride in-leakage.
- 3. Refer to Attachment 3 1000.042 Referred to Att. 3 and determined that Action Level 2 as shown on the form is incorrect and that Action Level 3 had been exceeded. Action Level 3 requires the plant to be shutdown as quickly as possible (typically within six hours) instead of the 100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> allowed for Action Level 2.
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-CHEMI Page 4 of 4 EXAMINEE'S COPY JPM INITIAL TASK CONDITIONS:
The plant had been operating at 100% for 215 days.
The shift chemist has just arrived in your office and has given you, the Shift Manager, form 1000.042A to review.
INITIATING CUE:
As Shift Manager, review the 1000 042A form for out of specification Feedwater chlorides.
Page 20 of 21 PROCEDURE REQUIREMENTS:
CHEMISTRY RE ONMENDATIONS.
/UL'O,O'rC&r /2ose Y cP / PAGE NUMBER:
MONITORING ACTIVITY Ar.kcfl 40 . o /F.,JF/ .+MO b,, ; /no ASL,~S, SAMPLING FREQUENCY:
TIME CLOCK ENDS:
oil,
. /w
(
DATE:
TINE:
CHEMIST REPORTING OUT-OF-SPEC. :
9- , / 7- 0 .I DATE : TIME:
T%yy PLi +f; 9-//3.-os /'/ -7i l U H i d e o u t R e t u r n f o r planned outage. Ifr'marked, then S h i f t Manager reviews (nay be N/A.
REVIEWED BY S H I F T MANGER: DATE : TIME:
I N SPEC TEST DATE I N SPEC TEST DATE i I N SPSC TEST 1 I DATE PARAMETER LIMIT __
TIME P-ETER --
RESULTS -
LIMIT TIME PARAMETER L gI_T ___
TIME CHEMIST E R I Y Y I N G DATE : NOTES :
I N SPEC. CONDITION: TIME:
CORRECTIVE ACTION TAKEN BY OPEFATIONS:
REVIEWED BY DATE : 1 SHIFT W A G E R : TIME : 1 FORM TITLE: FORM NO. CHANGE UNiT 1 STEAM GENERATOR MONVORING REPORT 1000.042A 013-010
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TALT2 Page Iof 4 UNIT: 1 REV # -&.-.- DATE:
TUOl NUMBER: A1JPM-SRO-TALT2 SYSTEMIDUTY AREA: ADMINISTRATIVE TOPIC - EQUIPMENT CONTROL TASK: QUARTERLY CHECK OF TEMPORARY ALTERATIONS JTA#: ANO-SRO-ADMIN-NORM-89 KA VALUE RO: 2.8 SRO:3,4 KA
REFERENCE:
2.2.1 1 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR:- OUTSIDE CR: BOTH: X SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: PERFORM SIMULATOR: LAB:
POSITION EVALUATED: RO: SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION T I E IN MINUTES: 20 MINUTES REFERENCE(S): 1000.028 Cha. 024-00-0 EXAMINEE'S NAME: SSN -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAlNST THE STANDARDS CONTAINED IN THlS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THlS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TALT2 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: The plant is in Mode 3 for turbine repairs. All Temporaw Alterations taqs are in olace.
TASK STANDARD: The examinee has reviewed the attached temporaw alteration and identified at least 2 administrative errors.
TASK PERFORMANCE AIDS: Temporaw Alteration with 3 errors.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-SRO-TALT2 Page 3 of 4 INITIATING CUE:
The Shifl Manager directs you to conduct a Quarterly Review of Temporary Alteration 03-1-009 per 1000.028 You have in hand the package as found in the Control Room file. Identify at least 2 administrative errors.
CRITICAL ELEMENTS (C) 2
('3 PERFORMANCE CHECKLIST STANDARD NIA SAT UNSA T
- 1. Review Temporary Alteration Examinee reviewed Temporary Package 03-1-009. Alteration Package 03-1-009.
- 2. Identify administrative errors in Examinee identified at least 2 of 3 Temporary Alteration Package errors on Temporary Alteration 03-1-009. Package 03-1-009:
Improper mode (only Mode 1 checked, all modes should be checked)
Installation authorization not signed r 1000.028E Integrated Drawing list is missing does not agree with 1000.028G, Affected Drawing list in TAP. E-13 sh. 1 and E-I 11 sh.
3 are not on 1000.028E.
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-TALT2 Page 4 of 4 EXAMINEE'S COPY JPM INITIAL TASK CONDITIONS:
The plant is in Mode 3 for turbine repairs.
All Temporary Alterations tags are in place INITIATING CUE:
The Shift Manager directs you to conduct a Quarterly Review of Temporary Alteration 03 009 per 1000.028. You have in hand the package as found in the Control Room file. Identify at feast 2 administrative errors.
ARKANSAS NUCLEAR ONE
- K > m~LE: E-DOC NO. CHANGE NO.
TEMPORARY ALTERATION FORM 1000.026-A 026-00-0 L TAP #: 03-1909 TAP Installation WO# 00033175 . TAP Removal W W O # W R #00014536
(?I 3 TAP ER # ER-ANO-2003-0906-00u I TITLE: 'C' Phase Main Transformer Removal ANO-1 IX[ ANO-2 ANO- Common 17 Q a Fn sC]
- If both units are affected, mark common.
Unit responsible forthe affected SSC, as defined in the Component Data Ease, will number and control the TAP.
r] Affected SSC:
Associated SSC:
Reason for lnstallation:
t Due to current olant conditions, removal of the deoraded
~ ~ " . - ~ C-Phase Main Transformer has been requested to I support the future installation of the replaced transformer.
1
-Nodes Plant Modes for whi~h @ 7 p-$4480) b TAP mayremain installed: C] 2 (mark all which apply): 11 3 0 4 o
0 5
6 during duration, installation Engineer: Date:
Independent Reviewer: Date:
Supervisor: Date: J, / 2 4 (03-Manager: Date: /1/t6/03 j
System Engineer:
System Engr Manager: Date:
Operations Manager: Date: /I / z ~ / o-3 OSRC Chairman: Date: N /&
Plant Manager: Date: I\ -&-6 >
val has been granted lMSTALLATIONAUTHORIZATION SM 1 CRS: Dale:
- . -. ~
REMOVAL AUTHORIZATION SM / CRS: Date:
t W N S A S NUCLEAR ONE f DOC TITLE: E-DOC NO. CHANGE NO.
TEMPORARY ALTERATION FORM 1000.028-A 026-00-0 TAP Serial No. 03-1-OW Page: 2 LIST OF EFFECTIVE PAGES (Additional sheets must be numbered and include the TAP serial number)
ARKANSAS NUCLEAR ONE K a 0 C TITLE: E-DOC NO. CHANGE NO.
. TEMPORARY ALTERATION FORM 1000.028-A 026-00-0 TAP Serial No. 03-1-009 Page: 3 Summary Description of temporary alteration:
This T-AK will provide the necessary instructions to support the temporary removal of the original Unit-1 C-Phase Main Transformer @-OIC).
Special Instruction:
3 ( The installation engineer (or designee) shall verify that the requirements of ER-ANO-2003-0906-00&3 have been implemented in the installationwork order (WO#00033175 Task W)). If certain steps, or work instructions, have been previously oerfomed, visually v e M e comleteness of the work and attach a copy of supporting documentation-tothe i Verification Signature:
Verify that a copy of the lation work order has been attached to this Temporary Alternation after installa
'=/c/o 5 ockout functions have been performeddunng functional testing ntinuity check described in ER-ANO-2003-090600823. Attach blies' structural support under WR# 00014479 and lsophase Bus Duct Blanks (Covers) for conduit openings per WR# 00014477. (Testing to verify properflow balance and capability of the lsophase bus cooling will be tested in conjunction with the test performed by the X-018 and X-01s lsoph NO-2003-0893-001 and will verify that the lsophase Bus Duct Blanks have an Verification Signature r s u M s i hu-h\h\;Y wl)p'&
t#.rfa\bA.
Removal of this T-Alt will be covered in a separate WO (presently WR# 00014536) iaw linked ER-ANO-2003-906-31 001. (See ER-ANO-2003-0906-001323 Section 5.2) The removal instructions will depend on the transformer model that will be installed as a replacement for X-OIC. The installation Engineer (or designee) must verify that the removal WO and supporting ER appropriately address all facets of the TAP and attach the supporting documentation (including the WO and ER) to this Temporary Alteration prior to removal.
Verification Signature:
Suggested Temporary Alteration Tag Locations:
lsophase Bus Duct Blanks Temporary Junction Box for Generator Lockout Circuit wiring installed nearlon X-O1C concrete pad.
I 1 Suggested Caution Cards 1 Locations None (Additional sheets must be numbered and include the TAP serial number)
I ARKANSAS NUCLEAR ONE
&-DOCTITLE: E-DOC NO. CHANGE NO.
TEMPORARY ALTERATION FORM 1000.028-A 026-00-0 i
TAP Serial No,03-14W Page: 4 VERIFICATION AND DOCUMENTATiON OF INSTALLATION NQE if partial installation is desired, Fom 1000.024E "Provisional Release" shall be complied with. This form shall be filed with the Temporary Aiteration Package, with a copy in the installation WO.
The lnstaliation Engineer 01 other ind temporacy alteration has been install INSTALLATION ENGINEER: DATE:
The Shift Manager or designee vetifi J++$=-
stalled Der Section 6.1 1.2.
SHIFT MANAGEWDESLGNEE: DATE: / ~/~/663 Copies of the Temporacy Alteration Package are forwarded to:
a) If OSRC final review has not been obtained, forward originai to OSRC promptly and file a copy in the Control Room; otherwise mark N/A.
FORWARDEDBY: &,/A DATE:
b) Manager, Design Engineering (Affeded Drawing List only)
FORWARDED BY: DATE: /z/gb~
/ - I C) Manager, System Engineering FORWARDED B DATE: -
/2/&c~
d) Control Room of other unit, if affected (otherwise NIA)
FORWARDED BY: &/A DATE: &/A
- 1. The Installation Engineer audit should be completed within 7 days of the installation of the temporary Alteration.
- 2. it Is not necessary to make copies of drawings lamer Wan 8% x 11".
- 3. TheTag Record Sheet (Form 1000.0288) and a copy of any Lifted Lead Logs used for this installation shall be filed with the TAP.
The Installation Engineer shall perfom an audit of th tion Package in accordance with Section 6.12.1.
tNSTALLATlON ENGINEER: DATE:
I ARKANSAS MUCLEAR ONE E-oocnn~: E-DOC NO. CHANGE NO.
TEMWRARY A L T E W O N FORM 1000.028-A 026-004 TAP Serial No. 03-1-009 Page: 5 VERIFICATION AND DOCUMENTATIONOF REMOVAL If pariial removal is desired, Foim 1000.024E 'Provisional Release" shall be complied with. This form shall be filed wiih the Temporary Alteration Package, with a copy in the Removal WO.
The Installation Engineer verifies that the temporary alteration has been removed and configuration restored per Section 6.16.2.
INSTALLATION ENGINEER: DATE:
The Shift Manager w designee verifies that the temporary alteration has been removed and configuration restored per Section 6.16.4.
SWIFT MANAGERJDESIGNEE: DATE:
Copies of this page of the closed-out Temporary Alteration Package are forwarded to:
A. Manager, Design Engineeiing FORWARDED BY: DATE:
- 6. Manager. System Engineeting FORWARDED BY: DATE:
If other unit was affected, remove their copy (otherwise NIA).
REMOVED BY: DATE:
SHIFT MANAGERIDESIGNEE: DATE:
Forward original Temporary Alteration Package to Records.
FORWARDED BY: DATE:
ARKANSAS NUCLEAR ONE P-DOC TITLE: E-DOC NO. CHANGE NO.
TEMPORARY ALTERATION AFFECTED DRAWING LIST FORM 1000.02843 025005 TAP Serial No. 03-1009 Page: 8 AFFECTED DRAWING LlST 1A. The Installation Engineer wiil list below in Column 1 all Category A 8 B drawings, affected by this Temporary Alteration (if none, enter "none"), and wili sign below. If addrtional space is required, additional coptes of this sheet may be attached. Provide sheet numbers in the upper right corner.
- 18. The System Engineer will review and concurwiththe information in column 1 and will sign below.
- 2. The Shift Manager will assign an individual to determine whether each listed drawing is filed in the Control Room and to mark Column 2 appropriately.
- 3. The Shift Manager will assign an individual to list each affected Contml Room drawing on the Temporary Alteration Integrated Drawing List and all required copies. As each drawing is listed, the individual will initial the table in Column 3 below ("NIA"ifnot in Control Room). When all have been listed, he wili sign below (even if "none" are listed).
- 4. When the Temporary Alteration is deared, the Shift Manager wiil assign an individualto dear each affected drawing from the Temporay Alterat,ion lntegrated Drawing List and all requir* copies. As each drawing is cleared, Column 4 below wi I be rnNaled When all have been cleared, . indrvKfualwill sign below.
. ~ ..the
- 5. At each quartefiy review, the person perfoning the review will enter the date of the review and initial below the date for each Control Room drawing to indicate that the listed drawing a pro rl listed on the Temporary Alteratron Integrated Drawing List. If additional columns are requ@red?adbitionalcopies of this sheet may be attached, with the information in Columns 1 and 2 repeated and Columns 3 and 4 diagonally lined through and marked "MA". (No review is required if no dmwings are listed.)
Affected drawings have been cleared fWm the integrated Drawing List and all copies: I Assigned Individual Date (Additional sheets must be numbered and include the TAP serial number)
I I
I ARKANSAS NUCLEAR ONE E-DOC TITLE: E 4 0 C NO, CHANGE NO.
TEMPORARY ALTERATION TAG RECORD SHEET . . 1000.028% 02600-0 TEMPORARY ALTERATION TAG RECORD SHEET TAP SERIAL NUMBER 03-1-009 Sheet -
7 -
A W N S A S NUCLEAR ONE n
&DOC WTLE: E-DOC NO. CHANGE NO.
TEMPORARY ALTERATION PACKAGE REVISION (TAPR) 1000.028-D 025505 Page 8 TEMPORARY ALTERATION PACKAGE REVISION (TAPR)
TAP Serial Number: 03-1509 TAPR Number: 1 ChangecYAdded Pages: 1.2.3.6.7.Attachment 11 8 Summary of Changes: INCORPORATED ER-ANO-2003-0906-002 Added wirina chan~esto address the nuisance alarms caused bv the X-O1C fire detedion disabled detectors which have been removed from service. Provide alternative method for supgortlna west end of lsoahase Bus Bushino Box. Corred W O # tvpos.
Justification of Changes: Prevents nuisance alarms from distradlna Ooerations personnel and from maskinq valid common trouble alarms from remainina fire detedion svstem inouts. Prov~desacceotable method for supoortinq west end of lsophase Bus Bushinc Box.
TAPR APPROVAL A YES response to a screenang questaon requires the apprwal of Management and OLiRC.
-THEN IF screening questions are answered NO.
obtain only a Systeqs-Qngineerlng Supervisor approval.
I Operations Manager :
OSRC Chairman :
Plant Manager :
I n INSTALLATION AUTHORIZATION SMlCRS : ate 12-13 !g
- . (additional sheets must be numbered and must include the TAP serial number) 1
e-wc n n ~ :
ARKANSAS NUCLEAR ONE E-DOC NO. CHANGE NO.
A TEMPORARY ALTERATION PACKAGE REVISION (TAPR) 1000.028-0 026-00-0 TEMPORARY ALTERATION PACKAGE REVISION (TAPR) 1 TAP Serial Number: 03-1509 TAPR Number: A..........................................
ChangedIAdded P a g e s : ~ d d t t * . ~ ~ ~ ~ ~ . ?.................
a**.~.O
! o~,imms. own Wmarked-uodrawinasE-113Sh2reU2andE:4!jmgy...~-
i Summary of Changes: esc: son
- a M d a l o n a with caa
-nd cola*? ...... % .............
/ t i o n o f a....................
Justification of Changes: C l a r i f i c a... i l s arleadv-. ............... ............. .............
- 1. Does this change require a revision to the original 50.59 Review UYES MNO
- 2. Does this change allow the Temporary Alteration Package to be applied to a different DYES MNO component, system . structure, or associated OSRC?
- 3. Does thls chanqe affed the basic function of a system, structure, or component ~ - o already 1 DYES MNO addressed by the originally approved temporary alteration? I
- 4. Does this change affed performance requirements in a manner OQ! already addressed by ~UYES MNO I
- or reaulatow reauirements to which the 1-UYES WNO plant is comrnitikd, not addressed by the approved ~ e m ~ o r a~lteration & Package?
TAPR APPROVAL NOTE A YES response to a screening question requires the approval of Maaagement and OSRC.
screening questions are answered NO, THEN obtain only a Systems Engineering Supervisor approval.
Date 12/4/2003 Date 12/4/2003 Date 12/4/2003 System Engineer .</A Date Systems Engineering Manager : $4 Date Operations Manager : Date OSRC Chairman : n/& Date Plant Manager :
. //
INSTALLATION AUTHORIZATIOA Date I
Date /2/cgd~
(additional sheets must b e numbered and must include the TAP serial number)
7pqp-03-l-a~q &
Page 10 The following detailed steps are for additional clarification of information already contained in the supporting ER for this T-Alt.
Per connection drawing E-113 Sheet 2 and E-471 Sheet 15, in C482:
lift wire at terminal 8E (Cable # U34DB Color: OR-BK) lift jumpe WYm&
jumper 2E to 8E 11 a
h d~l~103 (Cable # U34A5 Color: G#)
- I .
. $ +,
&p$yb3 64 gk v 4 lift wire at terminal 6E2 (Cable # U34DB Color: BK)
+/ jumper 3E to 5E2
ARKANSAS NUCLEAR ONE L a E-DOC TITLE: E-DOC NO. CHANGE NO.
TEMPORARY ALTERATION PACKAGE REVISION (TAPR) 1000.028-D 025-00-0 Page 11 TEMPORARY ALTERATION PACKAGE REVISION (TAPR)
TAP Serial Number: 03-1-009 , to %GO ,a(5(03 TAPR Number: _;?_
d ChangedIAdded Pages: Changed PaQes3 h Attachment 1 from ER-ANO-2003-0906-002 to ER-ANO-2003-0906-003 Summary of Changes: ER-ANO-2003-0906-003added to correct instruction for fire detection bvoass wlrina and added thhb~aass of the Operatina Relay to orevent inadvertent actuation, Enhancements from TAP 03-1-009 TAPR 2 incnroorated into ER for comoleteness.
Justification of Changes: 3 - 1 13 Sh2 Rev 2 contamed draflina errors not detectable until attemuted installation creference CR-1-2003-1212).Chanqes necessaw lo meet scooe.
the originally approved temporary alteration? I
- 5. Does this change deviate from codes, standards, or regulatory requirements to which the UYES &NO plant is committed, not addressed by the approved Temporary Alteration Package?
TAPR APPROVAL NOTE A YES response to a soreenxng questaon reqUrres the approval of Management and OSRC.
IF screening questions are answered NO, THEN obtain only a Systems Engineering Supervisor approval.
System Engineer Kf
?i~~pnr--~afi'n / zjssw?ttmbr/CR'S Date Systems Engineering Manager : d/& Date Operations Manager : pi //t Date OSRC Chairman : ,d Date Piant Manager : pi4 Date INSTALLATION AUTHORIZATION SMlCRS , ate / Z - F cC3 I I (additional sheeis must be numbered and must include the TAP serial number)
-17%-' 03 - I --c@
ER COVER SHEET R r m t h w r 3..
I ER #: ER-ANO-2W3-0906-003 I Revision #: 0 I Grade: N.0.R.80 Page 1of 1 1
Title:
Removal of Origlnal G-Phase Maln Transformer (will superscede ER-ANO-2003-0906-002)
System ID: Date Required:
Equipment ID: Sugg. Milestone:
ProblemlProposedSolutionNustification: (Attach additional sheets as required)
This ER will provide the engineering bases for T-Ait 03-1-009. Cannot revise ER-ANO-2W3-0906d02 and as a result this ER was initiated to superscede the original ER. [Note that ER-ANO-2003-0906-002 superceded ER-ANO-2003-0906400.
This . .. is necessarv as a result of a drawina error on E l 13-2 (ref CR-1-03-1212).
.revision Quality Classification: Non Safety Implementation:
Response Type: Evaluation Problem Resolution: (Attach additional sheets as required)
See Attached LBD Impacted 0 YES 8NO Responsible Engineer: fviehta,Niranian K Date: 12/4/2003
@ Technical Reviewer 0winas.Roaer Lacey Date: 12/5/2003 nDesian verifier Date:
@ Supervisor Allen.Rhouts E D 8 k 12/5/2003 a Engineering Manager Date:
PSRC Required PSRC Meeting Number: Date:
GMPO Date:
ER: ER-ANO-2003-0906-003 Engineering Request Revison: 0 I Review Results
Title:
Removal of Original C-Phase Main Transformer (will suoerscede ER-ANO-2003-090B002)
COMPUTER SUPPORT GROUP Package Mehta.Nirsn]an K TIGER TEAM Package Mehta,Nlranjan K via telecon for Saulsbeny,Da~yll 12104i2003 TIGER TEAM Packaae Mehta.Niran~anK via teleeon for Sauisbem Derrit 12/05/2003 UNIT 1 OPERATIONS
- - STANDARDS Packaoe
~ .~ - - .- K I Mehta Nlranlan ~
ma
. tal-n . TaulOl .lmsc T.
.. ....for 1710dl~m2 COMPUTER SUPPORT GROUP Flnal Team Mehta.Niranjan K via telecon f a Tayw.JamesT 1V05QW3 UNIT 1 OPERATIONS STANDARDS Final Team t Mehta.Niranian K via teleeon for Canih.Kenneth V 12/05/2003 i
c Page @ofl+
ARKANSAS MUCLEAR ONE EDOC TITLE: E-DOC NO. CHANGE NO.
TEMPORARY ALTERATION INTEGRATED DRAWING LIST 1000.028-E 025404 Page 1 of j
@ TEMPORARY ALTERATION INTEGRATED DRAWING LIST TAP DRAWINGS AFFECTED DATE DATE NUMBER INSTALLED REMOVED -
03-1-009 E-14-1, E-111-1,2, E-452-4, Z 2/5/03 E-113-1,2, E-471-15 04-1-007 M-230 Sh. 2 5110104 04-1-002 E-71 Sh. 14 5111/04 OP-1104.032 M-209 Sh. 4 3/3/05 Att. E M-219 Sh. 1 Maintain original in the Temporary Alteration file.
Distribute copies to: Contml Room Control Room Extension Auxiliary Operator Shack (UnR 1 only)
WCO Office (Unit 1 Only)
NOTE: all other copies shall be stamped "Unwnfrolled Copy" or words to that effect
TUOI NUMBER:
A1JPM-SRO-RC22 Page I of 4 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date: 311512005 TUOI NUMBER: A1JPM-SRO-RC22 SystemlDuty Area: Administrative Topic-Radiation Control Task: Calculate Stay times for yourself and another operator JA# ANO-SRO-ADMIN-NORM-162 KA Value RO 2.6 SRO 3.3 KA Reference G 2.3.10 Approved For Administration To: RO SRO IZi/
Task Location: Inside CR: Outside CR: Both: 3 Suggested Testing Environment And Method (Perform Or Simulate): Simulate Plant Site: Simulator: Perform Lab:
Position Evaluated: RO: SRO: X Actual Testing Environment: Simulator: Plant Site: Lab Testing Method: Simulate: Perform:
Approximate Completion Time In Minutes: 20 Minutes Reference(S): HP Survey Map of P36C, Pump Room 54.
Examinee's SSN:
Name:
Evaluatoi's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time Signed Date:
Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
TUOI NUMBER:
A1JPM-SRO-RC22 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS:
A hot spot has developed on Makeup PUMP P36C. An operator will be working in the vicinity of the reduction gear assembly in order to flush the lines and reduce the hot spot radiation field.
Using the supplied survey map, determine the individual stay times the operator without exceeding the annual administrative dose limit (Ignore dose received during transit). He has an accumulated annual Whole Body dose of 1750 mR (AN0 records). No additional dose has been received at any other site.
Also, calculate stay times if the air in the pump room was contaminated with a level of 0.40 DAC (stochastic) assuming no respirators are used.
Calculations should be based on AN0 Unit 1 Administrative dose limits. Provide answers with 3 significant figures (example 4.51 hours5.902778e-4 days <br />0.0142 hours <br />8.43254e-5 weeks <br />1.94055e-5 months <br />). Do not consider A U R A task requirements. Any required dose extensions have been processed and approved.
TASK STANDARD:
The examinee has correctly determined the stay times for an operator on the assignment.
TASK PERFORMANCE AIDS:
HP S u ~ e map y of P36C Pump Room, Room number 54 SIMULATOR SETUP:
N/A
TUOI NUMBER:
A1JPM-SRO-RC22 Page 3 of 4 INITIATING CUE: Determine the Stay time for an operator on the job. Also determine the stay time if the air in the pump room was contaminated with a level of 0.40 DAC (stochastic) assuming no respirators are used Provide answers with 3 significant figures (example X.XX hours).
CRITICAL ELEMENTS (c): 1,2. and 3 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN
- .. - -.-. .- . SAT C 1. Determine the HIGHEST general area dose rate in Examinee has determined the the area of the reduction gear assembly to be used HIGHEST general area dose rate from the survey map. in the area of the reduction gear assembly to be used from the survey map of P36C pump room.
C 2. Determine Stay time (to 3 significant figures) with Examinee has determined that no airborne contamination for both operators. the stay time for operator is 3.33 hrs plus or minus 0.01 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, Key: Max dose at AN01 is 2000 mR I I Operator has 1750mR. =>allowed dose 250mR I
I / 250mR = 3.33 hr, 75mWhr C 3. Determine Stay time( to 3 significant figures) WITH Examinee has determined that airborne contamination, the stay time for operator is 3.29hrs plus or minus 0.01 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
IDAC = 2.5mWhr => 0.40DAC = z l ,OmWhr Total rate = 75mRlhr + I.OmR/hr = 76mWhr I ,I - - -- . '
EXAMINERS CUE: This concludes the JPM.
END
TUOI NUMBER:
A1JPM-SRO-RC22 Page 4 of 4 EXAMINEE'S COPY INITIAL CONDITIONS:
A hot spot has developed on Makeup PUMP P36C. An operator will be working in the vicinity of the reduction gear assembly in order to flush the lines and reduce the hot spot radiation field.
Using the supplied survey map, determine the individual stay times for the operator without exceeding the annual administrative dose limit (Ignore dose received during transit). He has an accumulated annual Whole Body dose of 1750 mR (AN0 records). No additional dose has been received at any other site.
Also calculate stay times if the air in the pump room was contaminated with a level of 0.40 DAC (stochastic) assuming no respirators are used.
Calculations should be based on AN0 Unit 1 Administrative dose limits. Provide answers with 3 significant figures (example X.XX hours). Do not consider ALARA task requirements. Any required dose extensions have been processed and approved.
See handout for definitions.
INITIATING CUE:
Determine the Stay time for you an operator on the job. Also determine stay time if the air in the pump room was contaminated with a level of 0.40 DAC (stochastic) assuming no respirators are used. Provide answers with 3 significant figures (example X.XX hours).
I MAP NUMBER. 1A2-16 LOCATION U1 AUX 335' EL P36C PUMP ROOM. ROOM NUMBER 54 Aux building I DPM: 100~m2 No. Activity Dose Rate lnst HP-DR-170 posted: RM,RWPR Cal Due Date 12/31/2005 335 posted RA I Dose Rate Inst #2 RM-065 1
Iz .=I 1~ al)ue l Date 1213112005 I Count Inst RO-705 Gal Due Date 1213 112005 I
-- Count Inst. #2 RO-708 RP Supervisor Review:
All Radiation values are in memhour unless othmvise noted.
125 denotes gamma general area dose rates.
--- - -- - lIANl# 011256 Smear contanination values are in DPMilOO S q m unless 0th-ise noted. H. S. Denotes Hot Spot Kuidinp -. -..
- 12113 Denotes Ganuna Contadmar reading (30 m) 0 Denotes smear location (100 s q m ) Page 1 of 12 Denotes Cornact dose rate ( g m n a )
F a m to be retained for records
'12 B Denotes Beta Contact Dose Knte n ~en~tes I,, area r n h t~i ,
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1 JPM-SRO-EAL9 Page 1 of 4 UNIT: 1 REV # 0 DATE:
TUOI NUMBER: A1JPM-SRO-EAL9 SYSTEMIDUTY AREA: ADMINISTRATIVE TOPIC - EMERGENCY PROCEDURESIPLAN TASK: TAKE EMERGENCY DIRECTION AND CONTROL JTA#: ANO-SM-EPLAN-EMERG-302 KA VALUE RO: 2.6 SRO: 4.0 KA
REFERENCE:
2.4.29 APPROVED FOR ADMINISTRATION TO: RO: SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: NIA SRO: X ACTUAL TESTING ENVIRONMENT: SIMULATOR: X PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE(S): 1903.010 Chp. 037-03-0.1903.011. Cha. 028-00-0 EXAMINEE'S NAME: SSN -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
ADMINISTRATIVE JOB PERFORMANCE MEASURE TUOI: A1JPM-SRO-EALQ Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: The followina conditions exist:
Unit One reactor has tripped one hour aao. Reactor Buildina radiation levels are readina 190 Whr. RP reports radiation levels are 2000 mWhr from sample point SA-229. RB Sump level on L-1405 is steady at 60%. Aux.
Bldo. Sump level on L-4403 is risina. Dirtv Waste Drain Tank T-2OAIB levels are aoina up. SE calculates an RCS leak rate of 60 aam. RDACS is indicatina an offsite release is in oroaress.
TASK STANDARD: Examinee correctlv classifies this event as a GE per EAL 1.7 and makes notifications to alant personnel per step 4 of 1903.011S.
TASK PERFORMANCE AIDS: 1903.010 Attachments 1 and 3. and 1903.011
ADMINISTRATIVE JOB PERFORMANCE MEASURE Page 3 of 4 INITIATING CUE:
For the given plant conditions, determine the applicable EAL classification and initiate notifications through step 4 of the applicable Shifl Manager checklist in 1903.011.
CRITICAL ELEMENTS (C) 3. 5 (C) PERFORMANCE CHECKLIST STANDARD NIA SAT UNSAT
- 1. Compare event conditions with the Turned to Attachment 1 of 1903.010, Index of EALs, Attachment 1 of Index of EALs.
1903.010, Emergency Action Level Classification.
- 2. Tum to appropriate EAL and Turned to a specific EAL in Safety compare EAL criteria with event System Function, Attachment 3 of conditions. 1903.010.
(C) 3. Declare the emergency Declared or stated the event is a GE classification. based on EAL 1.7, Loss of or challenge to all three fission product barriers (not required to be stated).
I I I
- 4. Initiate immediate notifications. Referred to 1903.011. - - -
I I I I I I NOTE: Cue the examinee that the Unit 2 Shift Engineer is performing the initial notificat~onsper 1903011 after the examinee has stated that Untt 2 Shift Engineer (or control room communicator) has been requested.
+I I I I I
- 5. Begin completion of form Completed form 1903.011S GE 1903.011S, GE Emeqency Emergency Direction and Control Direction and Control Checklist for Checklist for Shifl Manager, thru step Shifl Manager. 4.
Examinee should fill in the data on items 1 and 2.
Examinee should simulate (or state) direction of the SE to complete the initial notification.
6 . Inform Control Room Staff of Informed Control Room Staff of GE.
Emergency Class declaration.
END
ADMINISTRATIVE JOB PERFORMANCE MEASURE Page 4 of 4 EXAMINEE'S COPY JPM INITIAL TASK CONDITIONS:
Unit One reactor has tripped one hour ago.
Reactor Building radiation levels are reading 190 Whr.
R P reports radiation levels are 2000 mWhr from sample point SA-229 R B Sump level on L-1405 is steady at 60%.
Aux. Bldg. Sump level on L-4403 is rising.
Dirty Waste Drain Tank T-20AlB levels are going up.
SE calculates an RCS leak rate of 60 gpm.
RDACS is indicating an offsite release is in progress.
INITIATING CUE:
For the given plant conditions, determine the applicable EAL classification and initiate notifications through step 4 of the applicable Shift Manager checklist in 1903.011.
Page 14 of 58 Page Iof 2 NUE This form is intended to be used by the person with Emergency Direction and Control when a Notification of Unusuai Svent has been declared.
- 01. Nozification of Unusuai Event declared:
Unit ___ Time -- Date -
- EMERGENCY CLASSIFICATION ANNOUNC-NT SHOULD BE MADE WITHIN 15 MINUTES OF THE DECLARATION**
- 02. EALN0.-
Description:
C]3. Notification Communicator 03.1 Single/Dual Unit Emergency 0 1 . Activate CNS IF CNS already activated for an NUE emergency class, THEN go to step 2 below.
Direct your unit's Shift Engineer to activate CNS in accordance with Attachment 9 of rhis procedure.
0 2 . Direct the opposite unit Shift Engineer to perform notifications using Form 1903.011-Y, Emergency Class Initial Notification Message.
03.2 Additional Notification Communicator is Available IF a Notification Communicator is available, THEN request the Notification Communicator to perform notifications in accordance with Form 1903.011-Y, Emergency Class Initial Notification Message.
- 04. Inform the Control Room staff of the Emergency Class declaration
- 05. Make the foilowing announcement over the plant paging system (dial 197):
"Attention all personnel. Attention all personnel. A Norification of Unusual Event has been declared on Unit - (One/Twe). All personnel continue normal activities unless instructed otherwise."
05.; Dial 191 and repeat the above announcement.
0 5 . 2 .Yake the above announcement over the EOF Public Address System (dial 199 and pause approximately 15 seconds).
FORM TITLE: FORM NO. REV.
NUE EMERGENCY DIRECTION AND CONTROL CHECKLIST 4903.011J 028-00-0
Page 15 of 55 Page 2 of 2 0 6 . [IF on-site personnel hazards exist, THEN direct implementation of protective actions as necessary.
0 6 . 1 Refer to Fonn 1903.030C, mLocalized Evaluation Checklist", to determine if a localized evacuation will be performed.]
- 07. an approach route to the plant site should be avoided, THEN instruct Security to direct incoming traffic. (Examples of this include security situations in which onsite/offsite personnel are directed to the EOF, radiological releases that prohibit entry to the site via either guard station, etc.)
0 8 . Direcr Chemistry personnel (Initial Dose Assessor) to implement procedure 1904.002, "Offsite Dose Projection - RDACS Computer Method".
Performed by:
FORM TITLE. FORM NO. REV.
NUE EWlERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011J 028-00-0
Page 1 of 2 ALERT This form is intended to be used by the person with Emergency Direction and Control when an Alert has been declared.
- 01. Alert declared: Unit Time Date
- EMERGENCY CLASSIFICATION ANNOUNCEMENT SHOULD BE MADE WITHIN 15 MINUTES OF THE DECLARATION**
- 02. Conditions warranting declaration of an A;ert:
EAL No.-
Description:
- 03. Notification Communicator 03.1 Single/Dual Unit Emergency 0 1 . Activate CNS IF CNS already activated for an Alert or higher emergency class, THEN go to step 2 below.
Direct your unit's Shift Engineer to activate CNS in accordance with Attachment 9 of this procedure.
q Use Section 8 of Attachment 9 if ERO is at risk due to site conditions (e.9. security event, toxic gas release, major onsite fire, etc). ERO will respond to rhe Aiternate EOF.
q use Secrion 1 of Attachment 9 for normal ERO cailout.
0 2 . Direct the opposite unit's Shift Engineer :e perform notifications using Form 1903.011-Y, Emergency Class Initial Notification Message.
03.2 Additional Notification Comunicator is Available
- 01. g a Notification Comunicator is available, THEN request the Notification Communicator to perform notifications in accordance with Form 1903.011-Y, Emergency Class Initial Notification Message.
- 04. Inform the Control Room staff of the Emergency Class declaration.
- 05. Inform both units' operators in the field to log onto the Emergency RWP.
0 6 . Make the fo1;owing announcement over the plant paging system (dial 197):
"Attention all personnel. Attention all personnel. An Alert Emergency Class has been declared on Unit (One/Two). Emergency response personnel report to your designated assembly areas. A;1 other personnel continue normal activities unless instructed otherwise."
0 6 . 1 Dial 197 and repeat the above announcement.
0 6 . 2 Make the above announcement over the EOF Public Address System (dial 199 and pause approximately 15 sec.)
FORM TITLE: FORM NO. REV.
ALERT EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011M 028-00-0
Page 18 of 58 Page 2 of 2 El1 [IF on-site personnel hazards exits, THEN direct implementation of protective actions as necessary.
0 7 . 1 Refer to Form 1903.030C, "Localized Evacuation Checklist", to determine if a localized evacuation will be performed.]
178. an approach route to the plant site should be avoided, THEN instruct Security 70 direct incoming traffic. (Examples of this include security situations in which onsite/offsite personnel are directed to the EOF, radiological releases that prohibit entry to the site via secondary guard station, etc.)
0 9 . Direct Chemistry personnel (Initial Dose Assessor) to the Control Room to implement procedure 1904.002, "Offsite Dose Prolection -
RDACS Computer Metnod".
Performed by:
FORM TITLE: FORM NO. REV.
ALERT EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011M 028-00-0
Page 20 of 58 Page 1 of 4 SAE This form is intended to be used by the SHIFT MANAGFJ7 when a Site Area Emergency has been deciared and the Shift Manager has the responsibility for Emergency Direction and Control.
- 01. Site Area Emergency declared:
Unit Time Date
- EMERGENCY CLASSIFICATION / PLANT EVACUATION ANNOUNCEMENT SHOULD BE MADE WITHIN 15 MINUTES OF THE DECLARATION**
- 02. EAL No.-
Description:
133. Notification Communicator 173.1 Single/Dual Unit Emergency 0 1 . Activate CNS IF CNS already activated for an Alert or higher emergency class, THEN go to step 2 below.
Direct your unit's Shift Engineer to activate CNS in accordance with Attachment 9 of this procedure.
C1 Use Section 8 of Attachment 9 if ERO is at risk due to size conditions (e.g. security event, toxic gas release, major onsite fire, etc). ERO will respond to the Alternate EOF.
C1 Use Section 1 of Attacnmenr 9 for normal ERO callout.
0 2 . Direct the opposite unit's Shift Engineer to perform notifications using Form 1903.011-Y, Emergency Class Initial Notification Message.
03.2 Additional Notification Communicator is Available 0;. IF a Notification Communicator is available, THEN request the Notification Communicator to perform notifications in accordance with Form 1903.0il-Y, Emergency Class Initial Notification Message.
- 04. Inform the Control Room staff of the Emergency Class declaration FORM TITLE FORM NO REV SAE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011P 028-00-0 SHIFT MANAGER
Page 21 of 58
?age 2 of 4 0 5 . Has a plant evacuation been performed?
NO - GO step 6.
q YES - perform the following announcement:
OA. Dial 197
- 03. Make the following announcement:
"Attention all personnel, Attention all personnel. A Site Area Zmergency has been declared on Unit - (One/Two). Emergency response personnel report to your designated assembly areas."
OC. Dial 197 and repeat the above announcement OD. Repeat the above announcement using the EOP public address system by dialing 199 and pausing approximately 15 seconds before making the announcement.
OE. c;o TO step 15.
Plant Evacuation Section
- 06. Determine the appropriate evacuation routes:
06.1 DOES a radiological or toxic gas release exist or is a release suspected, which is originating from the plant?
q YES - THEN determine the available routes from the chart below using wind direction.
-IF wind direction is From: -
THEN use Evacuation Routes 0 to 100 degrees C] 1 and 2 101 to 220 degrees q 1 22: to 359 degrees Clz NO - THEN use routes 1 and/or 2.
06.2 Check the appropriate routes in the plant announcement Step iO below.
- 07. Determine any areas of the plant to avoid during evacuation or special protective measures to be taken by plant evacuees.
- 08. Direcx Security to perform the following (ext. 3388, 3108 or 3109):
08.1 Use manual scanning to expedite evacuation, if necessary.
08.2 Perform initial accountability by (Time)
(30 minutes from SAE declaration)
FORM TITLE: FORM NO. REV.
SAE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011P 028-00-0 SHIFT MANAGER
Page 22 of 58 Page 3 of 4
- 09. Contact Radiation Zrotection (CAI - 5166 or CA2 - 3018):
09.1 Request Health Physics coverage :
a the planr exit porcal monitors.
09.2 Instruct Health Physics personnel at the controlled access exit point to relax decontamination and radiation protection measures as necessary in order to expedite evacuation of the controlled access area.
0 1 0 . [Make the following announcement using the plant paging system (dial 197):
"Attention all personnel. Attention all personnel. A Site Area Emergency has been declared on Unit -(One/Two). Emergency response and emergency standby personnel report to your designated assembly areas and perform initial accountability. All other personnel evacuate the plant using evacuation route(s) C] 1 C] 2 and proceed to the Atkins Emergency Worker Center."
If necessary, include in the announcement any plant areas to avoid, or special protective actions to be taken by plant evacuees:
010.1 Sound the evacuation alarm for approximately 10 seconds.
C]10.2 Repeat the announcement at least 2 times, alternating the announcement with the plant evacuation alarm.]
1 1 Make the foILowing announcement using the EOF public address system (dial 199 and pause approximately 15 seconds).
"Attention a i l personnel. Attention all personnel. A Site Area Emergency has been declared on Unit -(One/Two). Emergency response personnel report to your designated assembly areas.
n 1 2 . instruct all Control Room personnel (operators, chemists, RP, etc.) to log into the designated security card reader using "0000".
m 1 3 . Instruct both units' operators in the field to log into the nearest security card reader using "0000" and log onto the emergency RWP.
m14. Inform the opposite unit Control 3oom personnel to iog into the designated security card reader using "0000".
FORM TITLE: FORM NO. REV.
SAE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011P 028-00-0 SHIFT MANAGER
Page 23 of 58 Page 4 of 4 015. the incident extends into the Exclusion Area, THEN consider an Exclusion Area Evacuation.
Exclusion Area Evacuation is deemed necessary:
Perform the following if an Ui5.1 Request that the u.S. Army Corps of Engineers (teiephone number located in Zzergency Telephone Directory) control boat access to the portions of Lake Dardanelle within the exclusion area.
015.2 Direct Security to evacuate tne Generation Support Building (GSB) and all buildings outside the security fence but within the exclusion area.
Plant Evacuation Section Ends 0 1 6 . Direct Chemistry personnel (Initial Dose Assessor) to the Control Room to implement procedure 1904.002, "Offsite Dose Projection - RDACS Computer Yethod".
017. IF an approach route to the plant site should be avoided, THEN instruct Security to direct incoming traffic. (2xamples of this security situations in which onsite/offsite personnel are directed to inciude the EOF, radioiogicai releases that prohibit entry to the site via secondary guard station, etc.)
Serfcrmed by:
Shift Manager FORM TITLE. FORM NO. REV.
SAE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011P 02850-0 SHIFT MANAGER
Page 30 of 58 2age 1 of 4 This form is intended to be used by the SHIFT blANAGER when a General Emergency has been declared and the Shift Manager has the responsibility for emergency Direction and Control.
- 01. General Emergency declared:
Unit Time Date
- EMERGENCY CLASSIFICATION / PLANT EVACUATION ANNOUNCl?XENT SHOULD BE MADE WITHIN 15 MINUTES OF THE DECLARATION**
- 02. Condltrens warranting declaration of a General Emergency:
EAL No.-
Description:
- 03. Notrficatlon Communicator 03.1 S i n g l e / D u a l U n i t Emergency 0 1 . Activate CNS IF CNS already activated for an Alert or higher emergency class, THEN go to step 2 below.
Direct your unit's Shift Engineer to activate CNS in accordance with Attachment 9 of this procedure.
17 Use Section 8 of Attachment 9 if ERO is at risk due to site conditions (e.g. security event, toxic gas release, major onsite fire, ctc). ERO will respond to the Alternate EOF.
17 Use Section 1 of Attachment 9 for normal ERO callout.
0 2 . Direct the opposite unit's Shift Engineer to perform notifications using Form 1903.011-Y, "Emergency Class Initial Notification Message."
03.2 Additional Notification Comunicator is Available
- 01. IF a Notification Communicator is available, THEN request the Notification Com~unicatorto perform notifications in accordance with Form 1903.011-Y, "Emergency Class Initial Notification Message. "
- 04. Inform the Control Room staff of the Emergency Class declaration.
I GE EMERGENCY DIRECTION AND CONTROL CHECKLIST SHIFT MANAGER I 1903.OllS I 028404 I
Page 31 of 58
?age 2 of 4 175. Has a plant evacuation been performed, No - GO TO Step 6 C1 YES - THEN perform the following:
CIA. Dial 197 EB. Make the following announcement:
"Attention all personnel. Attention all personnel. A General Emergency has been declared on Unit -(One/Two). Zmergency response personnel report to your designated assembly areas."
UC. Dial 197 and repeat the above announcement.
O D . Repeat the above announcement using the ZCF pubbiic address system by dialing 199 and pausing approximately 15 seconds before making the announcement.
OZ. GO " step 15.
Plant Evacuation Section
- 06. Deternine the appropriate evacuation routes:
06.1 a radiological or coxic gas release exist or is a release suspected, which is originating from the plant?
C] YES - THEN determine the available routes from the chart below uslng wlnd direction.
-IF wind direction is From: -
THEN use Zvacuation Routes 0 to 100 degrees C] 1 and 2 101 to 220 degrees 1 221 to 359 degrees 2 C] - E N use routes 1 and/or 2 06.2 Check the appropriate routes in the plant announcenen:, step 1 0 below.
0 7 . Determine any areas of the plant to avoid during evacuarion and/or special protective measures to be taken by plant evacuees. List these instructions in plant announcement Step 10 below.
- 08. Direct Security to perform the following (ext. 3388, 3108 or 3109):
08.1 Use manual scanning to expedite evacuation, if necessary.
08.2 Perform initial accountability by (Time)
(30 minu:es from GE declaration)
FORM TITLE: FORM NO. REV.
GE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011S 028-00-0 SHIFT MANAGER
Page 32 of 58 Page 3 of 4
- 09. Contact Radiation Protection (CAI - 5166 or CA2 - 3018):
09.1 Request Heaith Physics coverage at the plant exit portal monitors.
09.2 Instruct Health Physics personnel at the controlled access exit point to relax decontamination and radiation protection measures as necessary in order to expedite evacuation of the controlled access area.
0 1 0 . [Make the following announcement using t h e p l a n t paging system ( d i a l 1 9 7 ) :
"Attention a l l personnel. Attention a l l personnel. A General Emergency has been d e c l a r e d on Unit -(One/Two). Emergency response and emergency standby personnel r e p o r t t o your designated assembly a r e a s and perform i n i t i a l a c c o u n t a b i l i t y . A l l o t h e r personnel evacuate t h e p l a n t using evacuation r o u t e ( s ) q 1 q 2 and proceed t o t h e Atkins Emergency Worker Center."
I f necessary, include i n t h e announcement any p l a n t a r e a s t o avoid, o r s p e c i a l p r o t e c t i v e a c t i o n s t o be taken by p l a n t evacuees:
m10.1 Sound t h e evacuation alarm f o r approximately 10 seconds 010.2 Repeat t h e announcement a t l e a s t 2 times, a l t e r n a t i n g t h e announcement with t h e p l a n t evacuation alarm.]
n i l . Make the following announcement using the EOF public address system (dial 199 and pause approximately 15 seconds).
"Attention all personnel. Attention all personnel. A General Emergency has been declared on Unit -(One/Two). Emergency response personnel report to your designated assembly areas."
0 1 2 . Instruct all Control Room personnei (operators, chemists, RP, etc.) to log into the designated security card reader using "0000".
0 1 3 . Instruct both units' operators in the field co log into the nearest security card reader using "0000" and log onto the emergency RWP.
0 1 4 . Inform the opposite unit Control Room personnel to log into the designated security card reader using "0000".
FORM TITLE: FORM NO. REV.
GE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.011S 028-00-0 I SHIFT MANAGER I I I
Page 33 of 58 Page 4 of 4 Qi5. Has an exclusion area evacuation been performed?
YES - GO TO Step 16 C1 9 - THEN perform the following:
C] Xequest that the U.S. Army Corps of Engineers (telephone number located in Emergency Telephone Directory) control boat access to the portions of Lake Dardanelie within the exciusion area.
C] Direct Security to evacuate the Generation Support auilding (GSBI and all buildings outside the security fence but within the exciusion area.
Plant Evacuation Section Ends 0 1 6 . Determine the appropriate Protective Action Recornvendation using Attachment 6, "Protective Action Recommendations (PAR) for General Emergency".
PAR No.
Review PAR criteria every 15 minutes. Notify within 15 minutes the NRC, State and local government of PAR changes in accordance with Form 1903.011-Y, "Emergency Class Initial Notification Xessage."
0 1 7 . Direct Chemistry personnel (Initial Dose Assessor) to the Control Room to implement procedure 1904.002, "Offsite Dose Prolection - RDACS Computer Method" 018. IF an approach route to the plant site should be avoided, THEN instruct Security to direct incolainq traffic. (Examples of this include 7
security situations in which onsite/offsite personnel are directed to the EOF, radiological releases which prohibit entry to the site via secondary guard station, etc.1 Performed by:
Shift Manager FORM TITLE: FORM NO. REV.
GE EMERGENCY DIRECTION AND CONTROL CHECKLIST 1903.01I S 028-00-0 SHIFT MANAGER
ES-301 Control Room 1 in Plant Systems Outline Form ES-301-2 Date of Examination: 911212005 Reactor Pressure
@ A l l control room (and in-plant) systems must be different and serve different safety functions; Type Codes Criteria for RO ISRO-i / SRO-U (Aftternate path 4-6 I 4 6 / 2-3 (C)ontroi room
@)direct from bank $9 1 5 8 / 64 (E)mer$encyor abnormal in-plant 21 121 12.1 (L)ow-Power 21 I 2 1 I 21 (N)ew or (M)odifted from bank including 1(A) 22 1 2 2 1 21 (P)revious 2 Exams 6 3 / s 3 / 5 2 (randomly selected)
WC.4 21 121 i 21 (S)imulator ES-301, Page 23 of 27
ES-301 Control Room 1 in Plant Systems Outline Form ES-301-2 Facili: ANO-1 Date of Examination: 9/12/2005 Exam Level (circle one): RO i Control Room systemsa ( 8 for RO; 7 for SRO-I; 2 or 3 for SRO- U)
Operating Test No.: One System 1 JPM Title Type Code. Safety Function 002 K4.10 RO 4.21SRO 4.4 (D)direct from bank 59 / 58 1 54 21 I 2 1 1 2 %
21 / 21 / 21 22 / 22 / 21 5 3 / 5 3 / 5 2 (randomly selected) 21 121 1 21 ES-301, Page 23 of 27
ES-301 Control Room Iin Plant Systems Outline F o m ES-301-2 Date of Examination: 911212005 002 K4.10 RO 4.21SRO 4.4 h9 / 5 8 1 54 (E)rnergency or abnormal in-plant 21 1 2 1 1 21 ES-30$, Page 23 of 27
Page 1 of 5 TUOI NUMBER: AIJPM-RO-EOP22 JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
System/Duty Area: Emergency and Abnormal Operations Task: Emergency Boration JA# A N 0 1-RO-EOP-EMERG-55 KAValueRO 4.0 SRO 4.6 KA Reference 007 EK3.01 Approved For Administration To: RO (Xi SRO Task Location: Inside CR: (Xi Outside CR: Both:
Suggested Testing Environment And Method (Perform Or Simulate #):
Plant Site: Simulator#: Perform Lab:
Position Evaluated: RO: SRO:
Actnal Testing Environment: Simulator #: Plant Site: Lab Testing Method: Simulate: Perform:
Approximate Completion Time In Minutes: 10 Minutes Reference@): 1202.012, Repetitive Tasks, 004-034 Examinee's Name: SSN:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time Signed # Date:
- TQ-202 attachment 9 is complete and on file for performance of this JPM for the current Reactor core configuration.
Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
TUOI NUMBER: AlPM-RO-EOP22 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shaIl review the "Briefing ChecMist System WaLkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS:
Two control rods failed to lnsett upon a reactor trip, CRD AC breakers did trip and the CRD Power Supply Breaker PBs on C03 have been depressed.
TASK STANDARD:
Boric acid is being injected into the RCS by the operating HPI pump from the BWST. This is an Alternate Success Path JPM.
TASKPERFORMANCE AIDS: 1202.012, RT-12, Emergency Boration NOTE: This is an Alternate Success Path JPM infended to be performed, not simulated NOTES TO IA OPERATORAND EAYMINER:
I. P-36C or B on the A-4 side musr be the operating HPIpump, withP-36A the ES pump.
- 2. Fail CV-1250 in the closedpodtion; thisforces the alternate optionfor Emergency Boration
TUOI NUMBER: AlJPM-RO-EOP22 INITIATING CUE: The CRSISM directs you to perform Emergency Boration per RT-12.
CRITICAL ELEh4ENTS (c): 4,6,8 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT
- 1. Set Batch Controller for maximum hatch size (999999). Batch set key depressed, 999999 gallons batch size set by depressing POSITIVE CUE: appropriate number keys. Depressed - - -
Batch Controller set to add 999999 gallons. enter and lower display keys in sequence (red LED next to display key should be on.).
- 2. Verlfy Condensate to Batch Controller (CV-1251) On C04, verified CV-1251 closed.
closed.
POSITIVE CUE:
CV-1251 green light on.
- 3. Open CV-1250. On C04, attempted to open CV-1250; identified that CV-1250 failed to - - -
FAULTED CUE: open.
CV-1250 green light on and red light off EXAMINER NOTE: Examinee should now transition to RT-2, Initiate BPI.
- 4. Open BWST outlq CV-1408. At C-16, opened CV-1408.
C - - -
P o s I n v E CUE:
CV-1408 red light on.
- 5. Place RCP Seal Inj. Block (CV-1206) in override. At C04, placed CV-1206 in O W .
POSITIVE CUE:
CV-1206 in O W .
- 6. m N BWST Outlet is open, THEN open W I Block On C-16, opened CV-1285.
C valve (CV-1285) to maintain PZR level 200 to 220.
POSITIVE CUE:
CV-1285 red light on.
EXAMINER NOTE: Examinee should now return to RT-12, Emergency Boration.
- 7. Place 3-way valve (CV-1248 in BLEED) On C04, placed CV-1248 in the BLEED position - - -
POSITIVE CUE:
CV-1248 blue light on, red light off.
TUOI NUMBER: AlJPM-RO-EOP22
/ EXAMMER NOTE: If PZR level is less than loo", inform examinee that PZR level is 110", slowly rising. 1
- 8. When PZR level is 2100, THEN establish maximum On C04, placed a second Letdown C Letdown flow. filter in service and adjusted CV-1223 to raise Letdown flow to at least - - -
POSITIVE CUE: 80-100 gpm.
Letdown flow is 80 gpm.
I I I NEGATIVE CUE:
Letdown flow is 40 gpm I I I I NOTE: TerminateJPM when maximum Letdown flow is established.
TUOI NUMBER: AlJPM-RO-EOP22 INITIAL CONDITIONS:
Two control rods failed to insert upon a reactor trip, CRD AC breakers did trip and the CRD Power Supply Breaker Trip PBs on C03 have been depressed.
INITIATING CUE:
The SMJCRS directs you to perform Emergency Boration per RT-12
ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLWR ONE TITLE REPETITIVE TASKS DOCUMENT NO CHANGE NO 1202.012 004-03-0 WORK PLAN EXP DATE TC EXP DATE NIA NIA SET # SAFETY-RELATED IPTE YES NO DYES @NO TEMP ALT DYES (XINO When you see t h e s e TRAPS Get t h e s e TOOLS Time Pressure Effective Communication Distractionllnterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShifVLast Shift Knowledge Peer Pressure Procedures ChangelOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME r'
FORM TITLE: I FORM NO. I CHANGE NO.
VERIFICATION COVER SHEET I 1000.006A 1 050-00-0
Page 1 of 3
- 12. Emergency Boration:
A. IF Boric Acid pump (P39A or B) and Batch Controller are available, THEN perform the following:
- 1) Set Batch Controller for maximum batch size (999999).
- 2) Verify Condensate to Batch Controller (CV-1251) closed.
- 3) Open Batch Controller Outlet (CV-1250).
- 4) Verify both Letdown Filters in service (F-3A and 8).
- 5) Record initial BAAT (T-6) level in.
- 6) Start available Boric Acid Pump(s) (P-39A or B or both).
- 7) Start Batch Controller by depressing RUN key.
- 8) Adjust Batch Controller Flow CNTRL VLV (CV-1249) to 100% open.
- 9) Adjust Pressurizer Level Control Setpoint to 220".
- 10) Open BWST Outlet to OP HPI Pump (CV-1407 or 1408).
- 11) WHEN PZR level is 2 loo", THEN establish maximum Letdown flow.
- 12) Perform the following as necessary to maintain MU Tank level 55 to 8 6 .
a) Close Batch Controller Outlet (CV-1250).
b) Stop running Boric Acid Pump(s) (P-39A, P39B).
c) Place 3-Way valve in BLEED.
d) WHEN MU Tank level is lowered to desired level, THEN perform the following:
(1) Return 3-Way valve to LETDOWN.
(2) Start available Boric Acid Pump(s) (P-39A or B or both).
(3) Open Batch Controller Outlet (CV-1250).
(12, CONTINUED ON NEXT PAGE)
Page 2 of 3
- 12. (Continued).
- 13) As time permits, determine actual required boration as follows:
a) Obtain required boron concentration from the Plant Data Book PP~B.
b) Calculate batch add required using Plant Computer OR
~ o l u b ~ ~ o i Concentration son Control (1103.004),Attachment A.3, "Calculation of Feed Volume For Batch Boration or Dilution". gal c) Use 1103.004, Attachment D, 'Volume of BAAT vs. Depth of Liquid" to determine desired final BAAT level. in
- 14) WHEN required amount of boric acid has been added per step 13)
OR as determined by Reactor Engineering, THEN perform the following:
a) Stop Boric Acid pump (P39A and 8).
b) Close Batch Controller Outlet (CV-1250) c) Verify MU Tank level 55 to 8 6 AND close BWST Outlet to OP HPI pump (CV-1407 or 1408).
d) Adjust Letdown flow to desired rate.
(12. CONTINUED ON NEXT PAGE)
Page 3 of 3
- 12. (Continued)
B. IF no Boric Acid pumps are available (P39A or B),
~ a t c h ~ o n t r o l lis e r&
p available, THEN perform the following:
a) Open HPI Block valve (CV-1220 or 1285) associated with running HPI Pump to maintain PZR level 200 to 220.
- 2) Place BWay valve in BLEED.
- 3) WHEN PZR level is 2 100, THEN establish maximum Letdown flow.
- 4) As time permits, determine actual required boration as follows:
a) Obtain required boron concentration from the Plant Data Book PPmB b) Calculate final BWST level for required boron addition using Plant Computer OR
~ o l u b i ePoison Concentration Control (1103.004), Attachment A.6.
"Continuous Feed and Bleed from BWST". n.
- 5) WnEN required amount of boric acid has been added per step 4)
OR as determined by Reactor Engineering, THEN perform the following:
a) Operate HPI as directed by CRS.
b) Adjust Letdown flow as directed by CRS END
JOB PERFORMANCE MEASURE UNIT : 1 REV # 2 DATE :
TUOI NUMBER: A1JPM-RO-LTOP1 SYSTEM/DUTY ARFA: REACTOR COOLANT SYSTEM TASK: ESTABLISH LTOP PROTECTION DURING COOLDOWN OF THE RCS JTA#: ANO1-RO-RCS-NORM-2 KA VALUE RO: 4.2 SRO: 4.4 KA
REFERENCE:
002 K4.10 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH :
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES REFERENCE(S): 1102.010 Chg. 053-11-0 EXAMINEE'S NAME: SSN - -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SAT1SFACTORY : UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE :
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
TUOI NUMBER: AIJPM-RO-LTOP1 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: The plant is in a cooldown with RCS temperature <300°F but >275"~. RCS pressure as indicated on PT-1020 "A" LOOP WR Pressure (ESAS-1) is Less than 380 psig.
TASK STANDARD: LTOP established with all HPI MOVs in the LTOP position and ERV block open and ERV setpoint switch in the 400 psig position.
TASK PERFORMANCE AIDS: 1102.010 Step 10.2 Simulator setup: On PMS establish Mode 3 in PMA.
TUOI NUMBER: AlJPM-RO-LTOPI INITIATING CUE:
The SM/CRS directs you to establish LTOP protection as per step 10.2 1102.010.
CRITICAL ELEMENTS (C): 2, 6 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT
- 1. Verify RC pressure is Verified pressure 1380 psig 1380 psig. on as indicated on PT-1020 POSITIVE CUE:
RC pressure is 360 psig.
- 2. Place ERV Setpoint hand On C04, positioned the ERV switch in 400 PSIG setpoint hand switch to the position. 400 PSIG position.
(C1 - - -
POSITIVE CUE:
400 PSIG amber light lit.
NEGATIVE CUE:
2450 PSIG white light lit.
- 3. Verify the ERV Isolation On C04, verified CV-1000 in (CV-10001 open. the open position by observing red light ON, POSITIVE CUE:
red light ON, green light green light OFF above HS-1000.
OFF.
NEGATIVE CUE:
green light ON, red light OFF.
- 4. If the plant computer is On the plant computer, used operating, verify the SVD function and selected following LTOP alarm T1016, T1017, T3071, PS3086 plant computer points and CON272 and verified that are do not have a each point does not have a quality of DEL: quality of DEL.
RCS Loop "A" Inlet Temperature Wide Range T1016 and Tl017 LTOP Trouble Alarm T3071 RCS Overpressurization Enable PS3086 LTOP Constant (272 "F)
. CON272 POSITIVE CUE:
T1016, T1017, T3071, PS3086, CON272 are not deleted.
TUOI NUMBER: AlJPM-RO-LTOP1 (c) 1 PERFORMANCE CHECKLIST I STANDARD / N/A I SAT / UNSAT
- 5. Verify pressurizer level Verified Pressurizer level is between 70" and 95". between 70 to 95" on level indicators located on C04.
POSITIVE CUE:
Pressurizer level is 85".
EXAMINER NOTE: If trainee asks, inform that Pressurizer level is being plotted and RCS cooldown rate is within the specifications of Att. 3.
I I I I I
- 6. Close the following HPI On C16 and C18, verified MOVs and place in the each HPI valve closed and LTOP position (may be placed key switch for each done in any order) : valve in the LTOP position I CV-1278 CV-1279 CV-1227 CV-1228 with white lights OFF.
1 1 POSITIVE CUE:
green lights ON for all valves, white LTOP in "NORMAL,,lights OFF for all valves.
1 NEGATIVE CUE:
red light ON or white LTOP in "NORMAL" light ON for any applicable mispositioned valve/key switch.
EXAMINER NOTE: Inform trainee that it is not desired to unprotect Pressurizer level computer points.
END
TUOI NUMBER: AlJPM-RO-LTOP1 INITIAL CONDITIONS:
The plant is in a cool down with RCS temperature <300°F but
>275'F.
RCS pressure as indicated on PT-1020 "A" Loop WR Pressure (ESAS-1) is less than 380 psig.
INITIATING CUE:
The SM/CRS directs you to establish LTOP protection as per step 10.2 1102.010.
ENTERGY OPEFWTIONS INCORPORATED ARKANSASNUCLEARONE
'TITLE PLANT SHUTDOWN AND COOLDOWN DOCUMENT NO. CHANGE NO 1102.010 053-114 WORK PLAN EXP DATE TC EXP. DATE N/A NIA SET # SAFETY-RELATED IPTE BYES ON0 DYES NNO TEMP ALT DYESBNO When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Distraction/lntermption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShiiLast Shift Knowledge Peer Pressure Procedures ChangeiOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME FORM TITLE: FORM NO. CHANGE NO.
VERIFICATION COVER SHEET 1000.006A 05090-0
PROC.lWORKPLAN NO. PROCEDURElWORK PLAN TITLE:
PAGE: 31 of 80 1102.010 PLANT SHUTDOWN AND COOLDOWN CHANGE: 053-11-0 10.0 Establishing Decay Heat Removal System Operation 10.1 IPgoingtoMode5, THEN implement Containment Closure Control per Decay Heat Removal and LTOP System Control (1015.002). Attachment G prior to placing plant in a condition where containment integrity is not required.
10.1.1 Complete Attachment G of 1015.002 for applicable valves listed in Category E/Locked Component Log (E-doc 1015 .OOlHl .
i4.3.2) 10.2 WHEN RC temperature is <300°F but >27S°F, THEN verify RC pressure is S380 psig as PT-1020 (SPDS P1020) and establish LTOP indicated on protection as follows :
10.2.1 Place ERV Setpoint hand switch in 400 PSIG position.
10.2.2 Verify ERV Isolation (CV-1000) open .
10.2.3 -
IF the plant computer is operating, THEN verify by using computer function SVD (LTOP) that the following LTOP alarm plant or OD computer points do have a quality of DEL.
RCS Loop "A" Inlet Temperature Wide Range
. (TI016 and T1017)
LTOP TROUBLE Alarm (T3071)
RCS Overpressurization Enable (PS3086)
LTOP Constant (272-8) (CON2721 10.2.4 -
IF the plant computer is NOT operating, T 5 N contact alarm.
Computer Support to enable LTOP
PROC.MIORK PLAN NO. PROCEDUREWORK PLAN TITLE:
PAGE: 32 of 80 1102.010 PLANT SHUTDOWN AND COOLDOWN CHANGE: 053-11-0 NOTE For LTOP concerns, maximum allowable Pressurizer level with RCS temperature c27Z0F Reactor Vessel head in place is:
- <105" at RCS pressures ,100 psig
- SI.50" at RCS pressures <I00 psig Annunciator "LTOP Trouble" (K09-E71 alarms at the following Pressurizer level setpoints with RCS temperature <27Z°F:
- 95" at RCS pressures ,100 psig I
- 140" at RCS pressures 5100 psig 10.2.5 Verify Pressurizer level is between 70' and 95".
10.2.6 Monitor and plot Pressurizer level vs. time during cooldown at least once every 15 minutes while RCS temperature is 5272-F (SR 3.4.11.1).
10.2.7 Limit RCS cooldown rate as necessary to maintain RCS temDerature above and to the riaht of the RCS Functional Specification curve,-
Attachment J.
10.2.8 For each of the followina HPI to P-32(A. B. C.
or D) Discharge valves, close valve and'place key switch in LTOP position.
10.2.9 -IF desired, THEN contact Computer Support to unprotect the alarm functions on the plant computer for PZR Level (L1001B and L1002B).
A. WHEN unprotected, THEN adjust setpoints below current LTOP requirements. N/A if not performed.
NOTE RCS maximum cooldown rate from 28O0F to 150'F is 50°F/hr, which equates to O.133~F/min.
10.3 Prior to cooling below 280°F, establish a cooldown rate of -
S50°F/hr.
JOB PERFORMANCE MEASURE Page 1 of 5 UNIT: I REV # 1 DATE:
TUOI NUMBER: A1JPM-RO-RCPO5 SYSTEM/DUTY AREA: REACTOR COOLANT PUMP SYSTEM TASK:- Shutdown P-32C & D after DH in service.
JTA#: ANO1-RO-RCP-NORM-3 KAVALUE RO: 2.8 SRO: 2.5 KA
REFERENCE:
003 A4.03 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 20 MINUTES REFERENCE(S): 1102.010 Chg. 053-11-0, 1103.006 Chg. 025-04-0 EXAMINEE'S NAME: SSN - -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
JOB PERFORMANCE MEASURE Page 2 of 5 TUOI NUMBER: AlJPM-RO-RCP05 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of 1064.023 Attachment 6 with the examinee.
JEW INITIAL TASK CONDITIONS: Plant cooldown is in progress. 'A" DHR is in service.
"C" and "D" RCPs are operating. Hot leg cooling is no longer required. RCS is at the desired boron concentration. Predictive maintenance is standing by.
TASK STANDARD: "C" and 'D" RCPs off and cooldown on DH commenced.
TASK PERFORMANCE AIDS: 1102.010 and 1103.006.
ADMINISTRATION NOTE:
Ensure 1 1 0 2 . 0 1 0 procedure has T-cold temperature recorded for simulator conditions.
JOB PERFORMANCE MEASURE Page 3 of 5 TUOI NUMBER: A1JPM-RO-RCP05 INITIATING CUE:
The SM/CRS dlrects you to stop "C" and "D" RCPs usrng "A" DHR loop in accordance with 1102.010, step 10.15.6. Steps 10.15.1 through 10.15.5 have been completed.
CRITICAL ELEMENTS (C): 1, 2, 4 N(C! PERFORMANCE CHECKLIST / STANDARD A SAT UNSAT
- 1. Establish DH cooler On C-14/C-18, adjusted DH outlet temp 10 to 15 cooler bypass/outlet OF below T-cold temp. valves until DH cooler (C! outlet temperature was POSITIVE CUE: between 10 "F to 15 'F - - -
DH Cooler outlet temperature below T-cold value is 10°F to 15 OF below T- recorded in previous cold temp. step.
- 2. Start HP Oil Lift Started HP Oil Lift Pumps Pump, Emergency HP Oil (P-63), Emergency HP Oil Lift Pump, and Backup Lift Pumps (P-80), and (C) Backstop Lube Oil Backup Backstop Lube Oil - - -
Pumps for "C" and 'D" Pumps (P-82) for "C" and RCPs . 'D" RCPs by placing handswitches on C-13 to POSITIVE CUE: the start position.
HP Oil Lift Pumps and Backstop Lube oil Pumps red lights ON green lights OFF.
- 3. Verify Backstop Lube On C-13, verified Oil Pumps running for Backstop Lube Oil Pumps "C" and 'D" RCPs . (Pal) running for 'C" and "D" RCPS. - - -
POSITIVE CUE:
Backstop Lube Oil Pumps red lights ON, green lights OFF.
- 4. Stop RCP s. Stopped "C" and 'D" RCPs by placing the POSITIVE CUE: handswitches on C-13 to (C) 'C" 'D" RCPs green lights ON the stop position. Last RCP was stopped within red lights OFF.
two minutes of stopping
-5. Verify HP Oil Lift Verified HP Oil Lift
- ~ - ~ ~
Pumps and Backstop Pumps and Backstop Lube Lube Oil Pumps remain Oil Pumps remain on on during RCP during RCP coastdown. - - -
coastdown.
POSITIVE CUE:
HP Oil Lift Pumps and Backstop Lube Oil Pumps red lights ON green lights OFF.
JOB PERE'ORMANCE MEASURE Page 4 of 5 without reverse rotation rotation.
POSITIVE CUE: maintenance.
Predictive maintenance reports shaft is stopped. Rcs loop flow indication Plant computer reverse rotation alarm remains clear.
- 7. When shaft has Stopped all oil pumps for stopped, stop ail oil "C" and 'D" RCPs by pumps for the idle placing the handswitches RCP. on C-13 in the PULL-TO-LOCK position. - - -
POSTTIVE CUE:
"C" and "D" oil pumps red lights OFF and green lights ON.
- 8. While RCS is >I50 OF, Verified seal injection maintain seal flow and ICW flow to RCP injection flow and ICW Seal Cooling Water Heat flow to RCP Seal Exchangers.
Cooling Water Heat - - -
Exchangers.
POSITIVE CUE:
Seal injection and seal cooling is being maintained.
- 9. Maintain ICW flow to Verified ICW flow to RCP RCP Motor Air Coolers. Motor Air Coolers.
POSITIVE CUE: - - -
RCP motor cooling is being maintained.
- 10. After RCP coast-down, Recorded DH cooler outlet record DH cooler temperature in step outlet temperature. 10.15.6 of 1102.010.
POSITIVE CUE: - - -
DH cooler outlet temperature is 204 OF.
- 11. Verify step change is Verified step change was
<15'F: CET temperature <I5 OF and recorded step (step 1) minus DH change in 1102.010.
cooler outlet temperature. - - -
POSITIVE CUE:
Step change is <15 OF.
END
JOB PERFORMANCE MEASURE Page 5 of 5 TUOI NUMBER: AlJPM-RO-RCPO5 JPM INITIAL TASK CONDITIONS:
Plant cooldown is in progress.
"A" DHR is in service.
"C" and "D" RCPs are operating.
Hot leg cooling is no longer required.
RCS is at the desired boron concentration.
Predictive maintenance is standing by.
INITIATING CUE:
The SM/CRS directs you to stop 'C" and "Do RCPs using "AN DHR loop in accordance with 1102.010, step 10.15.6. Steps 10.15.1 through 10.15.5 have been completed.
ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLEAR ONE
'TITLE PLANT SHUTDOWN AND COOLDOWN DOCUMENT NO CHANGE NO 1102.010 053-11-0 WORK PLAN EXP DATE TC EXP DATE NIA NIA SET # SAFETY-RELATED IPTE NYES ON0 WES HNO .
TEMP ALT DYES B N O When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Dlstraction/lnterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShiftlLast Shift Knowledge Peer Pressure Procedures ChangelOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME FORM IIRE: FORM NO. CHANGE NO.
VERIFICATION COVER SHEET 1000.006A 050-00-0
PR0C.WORK PLAN NO. PROCEDUREWORK PLAN TITLE:
PAGE: 36 of 80 1102.010 PLANT SHUTDOWN AND COOLDOWN CHANGE: 053-11-0 If the RCS is to be opened after cooldown, it is desirable to run the RCPs in parallel with the Decay Heat system to cool the RCS hot legs.
This helps to prevent flashing in the hot legs when the RCS is depressurized. RCP NPSH limits of Att. A must be met during RCP and DH system parallel operation.
RCPs should be secured together or as near together as feasible 10.15 WHEN CET temperature is between 166°F and 270°F AND when cooling RCS hot legs is no longer desired, THEN secure RCPs as follows:
1 0 15.1 IF performed, -
THEN verify Acid Reducing Phase of the Reactor Coolant Shutdown Chemistry per RCS Shutdown Chemistry Program (1604.050i complete 10.15.3 Verify RCS at final desired boron concentration. -
10.15.4 Record T-cold temperature used for plotting cooldown rate: OF 10.15.5 Stop RCS cooldown. -
L CAUTION If in Mode 5 and adequate margin does not exist to 200°F RCS temperature, an unexpected mode change may occur when DH cooler outlet temperature is adjusted to <15OF below T-cold temperature.
NOTE P
Plant Computer points T1406 and T1407 are the most accurate indication of DH cooler outlet temperature and should be used when available.
10.15.6 The following steps should be performed expeditiously to minimize RCS heatup:
A. Prior to stopping RCPs, adjust DH cooler -
outlet temp to c15OF below T-cold temp used for plotting cooldown rate.
B. Stop both RCPs per Reactor Coolant Pump -
Operation (1103.0061, "RCP Stop' section.
C. Record DH cooler -
outlet temperature OF.
PROC.M(ORK PLAN NO. PROCEDUREWORK PLAN TITLE:
PAGE: 37 of 80 1102.01 0 PLANT SHUTDOWN AND COOLDOWN CHANGE: 053-11-0 NOTE Step change limit of s1S0F is applicable only during transition from RCP operation to DH Removal. This step change must be included when calculating cooldown rate.
D. Check step change is ~15°F: -
T-cold temperature (step 10.15.4)minus DH cooler outlet temperature =
Step Change = OF.
NOTE sO°F/hr is equivalent to 12.S0F change per 15 minute plot.
>2S0P change in c30 minutes is a violation of Tech Spec cooldown limit.
10.15.7 Slowly adjust DH cooler outlet temp to establish RCS cooldown rate <SO°F/hr (<0.83°F/minl.
10.15.8 desired by Chemistry department, THEN continue cycling SG levels until ready for wet layup.
10.16 Continue cooldown plot as follows:
Plot DH Cooler outlet temperature from step 10.15.6.C Stop plotting T-cold.
Start plotting DH Cooler outlet temperature.
10.17 g required by the Surveillance Test Schedule or the Operations Manager, THEN verify Condensate, Feedwater and Steam System Tests (1305.032). Supplement 3 and 4 , MSIV Instrument Air System Leak Test is in progress or has been completed.
10.18 Secure main steam heating to Low Pressure Feedwater Heaters (E-2A and E-2B) by closing the following valves, N/A if main steam heating is not being used:
. Main Steam to E-2B Control Valve (CV-3021A)
Main Steam to E-2A Control Valve (CV-3028A)
Main Steam Heating to Feedwater Heater E-2A (CV-3028)
Main Steam Heating to Feedwater Heater E-2B (CV-3021) 10.19 IF degassing was required, THEN complete degassing before reducing RC pressure below that required to maintain adequate letdown flow rate.
ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLEAR ONE TITLE REACTOR COOLANT PUMP OPERATION DOCUMENT NO. CHANGE NO 1103.006 025-04-0 WORK PLAN EXP. DATE TC EXP DATE NIA NIA SET # SAFETY-RELATED IPTE EYES ON0 DYES EN0 TEMP ALT BYES O N 0 When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Distractionllnterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or interpretive Guidance Peer Check First ShiftlLast Shift Knowledge Peer Pressure Procedures ChangelOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME FORM TITLE: FORM NO. CHANGE NO.
VERIFICATION COVER SHEET 1000.006A 050-00-0
PROC.MTORK PLAN NO. PROCEDUREMTORK PLAN TITLE:
PAGE: 29 of 48 1103.006 REACTOR COOLANT PUMP OPERATION CHANGE: 025-044 10.0 RCP Stop 10.1 IF RCP is tripped
?% emergency manual trip is required, THEN refer to Reactor Coolant Pump Trip (1203.022) 10.2 IF time permits, THEN contact predictive maintenance to install backup indication of RCP zero s ~ e e d~ r i o rto RCP stop.
(0-3-1)
_I CAUTION Stopping or shifting RCPs or changing RCP loop configuration when RPS is
. reset can cause a reactor trip or an ICS runback.
Stopping the last RCP prior to bypassing EPIC will cause EPW actuation.
10.3 -
IP RPS is reset, AND NOT inThutdown Bypass,
-perform the following:
TKEN Maintain 1 RCP per loop Notify load dispatcher of any load change.
IF stopping 1 of 4 RCPs, THEN reduce power to 560%
I1 CAUTION I
1 Operation with only 1 RCP in each loop is permitted for 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> with the Rx Critical per TS 3.4.4 Condition A. Mode 3 is required within an additional 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> pkr TS 3 . 4 . 4 Condition B.
IF stopping 1 of 3 RCPs, resulting in 1 pump per loop,
- reduce power to 540%.
THEN
PROC.fWORK PLAN NO. PROCEDURUWORK PLAN TITLE:
PAGE: 30 of 48 1103.006 REACTOR COOLANT PUMP OPERATION CHANGE: 025-04-0 CAUTION Single pump operation in excess of 2 minutes may cause pump damage due to inadequate flow through the hydrostatic bearing.
~p NOTE Computer alarm BACKSTOP LO FLOW will not clear until backstop oil pumps are running with adequate flow. (not applicable for P-32B) 10.4 Stop RCP(s) as follows:
10.4.1 -IF P-32A, THEN perform the following:
NOTE During RCP start, running only one HP Oil Lift Pump will insure adequate HP Oil Lift pressure.
A. Start the following pumps:
HP Oil Lift Pump (P-63A)
Emergency HP Oil Lift Pump (P-80A)
NOTE Flow through each Backstop Lube Oil Pump and Backup Backstop Lube Oil Pump can be verified utilizing the following computer points:
B. Start the BACKUP Backstop Lube Oil Pump (P-82A).
C. Verify Backstop Lube Oil Pump (P-81A) indicates running.
D. Stop P-32A.
NOTE P-32B has a mechanical anti-reverse rotation device that is extremely noisy during startup and coast down.
E. IF only one RCP remains running, THEN stop the remaining RCP within 2 minutes
PROC.MIORK PLAN NO. PROCEDUREWORK PLAN TITLE:
PAGE: 31 of 48 1103.006 REACTOR COOLANT PUMP OPERATION CHANGE: 02544-0 10.4.2 IF P-32C, THEN perform the following:
NOTE During RCP start, running only one HP Oil Lift Pump will insure adequate HP Oil Lift pressure.
A. Start the following pumps:
HP Oil Lift Pump (P-63Cl r Emergency HP Oil Lift Pump (P-80Cl NOTE Flow through each Backstop Lube Oil Pump and Backup Backstop Lube Oil Pump can be verified utilizing the following computer points:
- 8. Start the BACKUP Backstop Lube Oil Pump (P-82C)
C. Verify Backstop Lube Oil Pump (P-81C) indicates running.
D. Stop P-32C.
NOTE P-32B has a mechanical anti-reverse rotation device that is extremely noisy during startup and coast down.
E. F only one RCP remains running, THEN stop the remaining RCP within 2 minutes
PROC.NYORK PLAN NO. PROCEDURENYORK PLAN TITLE:
PAGE: 32 of 48 1103.006 REACTOR COOLANT PUMP OPERATION CHANGE: 025-04-0 10.4.3 -
IF P-32D, THEN perform the following:
NOTE During RCP start, running only one HP Oil Lift Pump will insure adequate HP Oil Lift pressure.
A. Start the following pumps:
HP Oil Lift Pump (P-63D)
Emergency HP Oil Lift Pump (P-BOD)
NOTE Flow through each Backstop Lube Oil Pump and Backup Backstop Lube Oil Pump can be verified utilizing the following computer points:
B. Start the BACKUP Backstop Lube Oil Pump (P-82D).
C. Verify Backstop Lube Oil Pump (P-81D) indicates running.
D. Stop P-32D.
NOTE P-32B has a mechanical anti-reverse rotation device that is extremely noisy durins startup and coast down.
E. g only one RCP remains running, THEN stop the remaining RCP within 2 minutes.
10.4.4 -
IF stopping P-328, THEN start P-63B OR P-SOB.
NOTE P-32B has a mechanical anti-reverse rotation device that is extremely noisy durins startup and coast down.
A. Stop P-32B B. F only one RCP remains running, THEN stop the remaining RCP within 2 minutes
PROC.MIORK PLAN NO. PROCEDURENVORK PLAN TITLE:
PAGE: 33 of 48 1103.006 REACTOR COOLANT PUMP OPERATION CHANGE: 025-04-0 10.5 Perform the following during RCP coast down:
10.5.1 -IF P-32A stopped.
THEN verify the following pumps remain on:
HP Oil Lift Pump (P-63A)
Backstop Lube Oil Pump (P-81Al 10.5.2 -
IF P-32C stopped, THEN verify the following pumps remain on:
HP Oil Lift Pump (P-63C)
Backstop Lube Oil Pump (P-81Cl 10.5.3 -
IF P-32D stopped, THEN verify the following pumps remain on:
HP Oil Lift Pump (P-63D)
Backstop Lube Oil Pump (P-81Dl 10.5.4 -
IF P-328 stopped, THEN verify HP Oil Lift Pump (P-638)remains on 10.6 Verify shaft stops, without reverse rotation, as follows:
Verify Predictive Maintenance or Shift Engineer contacted to install backup indication of zero speed.
IF associated RCS loop flow is no longer dropping,
- E-fiEN consider the shaft stopped.
Plant computer reverse rotation alarm remains clear.(not applicable for P-32Bl RCP P32-D REVERSE ROTATION (FS6513)
RCP P32-C REVERSE ROTATION (FS65121 RCP P32-A REVERSE ROTATION (FS6510)
NOTE Reverse rotation is indicated by the following:
Computer alarm based on reverse lube oil flow RCP high vibration RCP motor bearing high temperature 10.7 -
IF reverse rotation indicated, THEN trip reactor.
10.7.1 Trip running RCP (s).
10.7.2 Refer to Reactor Trip (1202.001)
PROC.WORK PLAN NO. PROCEDUREWORK PLAN TITLE:
PAGE: 34 of 48 1103.006 REACTOR COOLANT PUMP OPERATION CHANGE: 025-04-0 10.8 WHEN shaft has stopped, THEN stop all oil pumps for the idle RCP by placing handswitches in PULL-TO-LOCK. (Backstop Lube Oil Pump not applicable to P-32B)
.. Emergency HP Oil Lift Pump (P-80A thru D)
HP Oil Lift Pumps (P-63A thru D)
. Backstop Lube Oil Pumps (P-81A,C, and D)
Backup Backstop Lube Oil Pumps (P-82A,C, and D) 10.9 While RCS is >150°F, maintain seal injection flow and ICW flow to RCP Seal Cooling Water Heat Exchangers (E-25A thru D).
10.9.1 Maintain ICW flow to RCP Motor Air Coolers RCP Motor Air Coolers (E-41A1 and E-41A2)
RCP Motor Air Coolers (E-41B1 and E-41B2)
RCP Motor Air Coolers (E-41C1 and E-41C2)
RCP Motor Air Coolers (E-41D1 and E-41D2) 10.10 IF RCP stop at power, perform the following:
10.10.1 Lower the U W HI-Load Limit 5% below runback limit.
NOTE RCP breaker status (normal or tripped) feeds NSSS Index Point which is used in the heat balance power calculation.
10.10.2 Verify Plant Computer reflects current RCP breaker status on ZSlH11, ZSlHl2, ZSlH21 and ZSlH22.
10.10.3 IF breaker status is incorrect.
%EN contact Computer Support to update Plant Computer to match current breaker status.
NOTE The Temuerature Comuensated Total Flow (XWRCFT) and RC Pressure (P1021, P1023, $1038. ~1039: alarm limits for the Plant Computer are dependent upon RCP combination. Normally Plant Computer alarm setpoints are operator adjustable, however, these points are some of the alarm points that are blocked that are carried on Tech Spec Cross-check log (OPS-A24). Refer to Unit 1 Operations Logs (1015.003A),Attachment C for these alarm limits.
10.10.4 Request Computer Support to adjust XWRCFT and RC pressure (4 points) alarms for current RCP status.
10.10.5 Continue plant operations per Power Operations, 1102.004
JOB PERFORMANCE MEASURE UNIT: 1 REV # 1 DATE :
TUOI NUMBER: AIJPM-RO-EOP16 SYSTEM/DUTY AREA: EMERGENCY AND ABNORMAL OPERATIONS TASK: PERFORM ACTIONS REQUIRED TO CORRECT OVERCOOLING OF THE RCS (DUE TO TBVs)
JTA#: ANOI-RO-EOP-EMERG-14 KA VALUE RO: 3.4 SRO: 3.7 KA
REFERENCE:
039 A2.04 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: PERFORM LAB:
POSITION EVALUATED: RO: SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 5 MINUTES REFERENCE(S): 1202.003 Chg. 005-01-0 EXAMINEE'S NAME: SSN - -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SICNE.? .--... . . ....-. . . >ATE: .. .... -.
,SL';?I?.T;IE 1?:2:CATTS ':'dl2 ???I :US BE?!! CCKl'Ai?F3 T3 ITS AiDF:.ICA3LE ?RCC?CIJRE BY A L'UhL:FTED :N31V1?'JAL N O T ?!(E LX.W,!IllfE Ah!D IS Z!.'RRZ!,J'? '/!YT;l THAT XLVIS13b:.
TUOI NUMBER: AlJPM-RO-EOPl6 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: The reactor is tripped and the plant is in an over-cooling event at this time.
TASK STANDARD: "B" MSIV closed.
TASK PERFORMANCE AIDS: Step 19 from 1202.003.
SIMULATOR SETUP: 100% power, f a i l turbine bypass v a l v e s CV-6687 and CV-6688 100%
open then t r i p the reactor and reduce letdown.
TUOI NUMBER: AlJPM-RO-EOP16 INITIATING CUE:
The SM/CRS directs you to check turbine bypass valves closed per step 19 of the Overcooling EOP.
CRITICAL ELEMENTS (C): 2, 3, 4 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAY
- 1. Check turbine bypass Identified that CV-6687 and valves closed. CV-6688 are full open (by valve position indication on FAULTED CUE: panel C03).
CV-6687 and CV-6688 are 100%
open.
- 2. Place turbine bypass valve On panel C03, placed turbine hand/auto station for "B" bypass valve hand/auto (C) OTSG in HAND and close. station for "8" OTSG in HAND and attempted to close POSITIVE CUE: CV-6687 and CV-6688.
"B" turbine bypass valve controller in HAND but valves NOT responding.
I I I I I EXAMINER NOTE: Inform examinee that an operator has been dispatched to locally close TBVs and reports they can NOT be closed locally.
I I I I I (C)
POSITIVE CUE:
Green light ON, red light OFF On panel C09, closed 'B" OTSG MSIV CV-2692.
I l l for CV-2692.
- 4. Open Feedwater Pumps On panel C03, opened (C) Discharge Crosstie CV-2827.
CV-2827.
POSITIVE CUE:
Red light ON, green light OFF for CV-2827.
POSITIVE CUE:
"A" MFP is tripped.
TUOI NUMBER: AlJPM-RO-EOP16 II II
- 6. Operate ATM Dump Control On panel C09, adjusted the System for "B" OTSG to "B" OTSG atmospheric dump stabilize RCS temperature.
I control system (CV-2618 &
CV-26191 to stabilize RCS 1-1-----1 I I POSITIVE CUE:
RCS temperature is stable.
temperature (as necessary).
EOP will now send examinee to step 25 since the overcoolzng is terminated.
I END
TUOI NUMBER: AlJPM-RO-EOP16 INITIAL TASK CONDITIONS:
The reactor is tripped and the plant is in an over-cooling event at this time.
INITIATING CUE :
The SM/CRS directs you to check turbine bypass valves closed per step 19 of the Overcooling EOP.
ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLEAR ONE TITLE: OVERCOOLING DOCUMENT NO. CHANGE NO.
1202.003 005614 WORK PLAN EXP. DATE TC EXP. DATE NIA NIA SET # SAFETY-REIAED IPTE lEifYES ON0 BYES BNO ,
TEMP ALT OYES E N 0 When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Distractionllntermption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShifULast Shift Knowledge Peer Pressure Procedures ChangelOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME FORM TITLE: FORM NO. CHANGE NO.
VERIFICATION COVER SHEET 1000.006A 050-00-0
INSTRUCTIONS CONTINGENCY ACTIONS
- 18. Check ATM Dump ISOL valves closed 18. Perform the following:
(CV-2619 and 2676).
A. IF associated ATM Dump Control System is being used to control SG press, THEN verify proper control:
SG A SG B CV-2676 ATM Dump ISOL CV-2619 ATM Dump CV-2668 CNTRL CV-2618 B. IF associated ATM Dump Control System is being used to control SG press, THEN close ATM Dump ISOL valve:
SG A SG B CV-2676 ATM Dump ISOL CV-2619 ATM Dump CV-2668 CNTRL CV-2618
A. IF TURB BYP valve fails to close, THEN dispatch an operator to close failed TURB BYP valve locally, while continuing with this procedure.
(19. CONTINUED ON NEXT PAGE)
INSTRUCTIONS CONTINGENCY ACTIONS
- 19. (Continued). B. IF associated SG press drops below 700 ~ s i a
'OR TURBFYP valve cannot be closed locally, T
k J
@ perform the following:
- 1) Close associated MSIV:
SG A SG B CV-2691 MSlV CV-2692 CV-6689 TURB BYP CV-6687 CV-6690 valves CV-6688
- 2) LF: MFW pumps are operating, THEN perform the following:
a) Open Feedwater Pumps DlSCH Crosstie (CV-2827).
(1) 1E CV-2827 fails to open,
-THEN actuate EFW AND verify proper actuation and control (RT 5).
b) Trip associated MFW pump:
SG A SG B CV-2691 CV-2692 B MFW pump A MFW pump -
c) both MFW pumps are tripped, THEN actuate EFW verify proper actuation and control (RT 5).
ATM Dump CV-2676 CV-2619 ATM Dump
- 4) overcooling is terminated, THEN GO TO step 25.
Page 1 of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 1 Date:
TUOI NUMBER: AIJPM-RO-HYD03 S y s t e d u t y Area: Hydrogen Recombiner and Purge Control System Task: Place Hydrogen Recombiner M55B in Operation JA# ANOI-RO-RBH2-NORM-I KA Value RO 4.0 SRO 4.0 KA Reference 028 A4.01 Approved For Administration To: RO 3 SRO IXI Task Location: Inside CR: 4 Outside CR: Both:
Suggested Testing Environment And Method (Perform Or Simulate #):
Plant Site: Simulator#: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Simulator #: Plant Site: Lab Testing Method: Simulate: Perform:
Approximate Completion Time In Minutes: 15 Minutes Reference@): 1104.031 Chg. 01443-0 Examinee's Name: SSN:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time - Stop Time Total Time Signed # - Date:
- TQ-202 attachment 9 is complete and on file for performance of this JPM for the current Reactor core configuration.
Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
TUOI NUMBER: A1JPM-RO-HYD03 TfE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist System WaIMhrough" portion of OP 1064.023Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS:
A LOCA has occurred. Containment hvdrogen concentration is 2.5%. Both hydrozen recombiners are shutdonn. Containment pressure is 26.0 psia. Pre-LOCA containment temperature was 120°F.
TASK STANDARD:
Hvdro@x recombiner M55B in operation at power settine, of 68.0 KW to 7W.0 KW on JI-1001.
TASK PERFORMANCE AIDS:
1104 031. sectron 8 Oand Att B
TUOl NUMBER: AIJPM-RO-HYDO3 INITIATING CUE: The CRSISM directs you to place both hydrogen recombiners (M55AiB) in standby and then place M55B in operation.
Note: Your task is complete when the power you have determinedfor recombiner operation is achieved.
CRITICAL ELEMENTS (c): 2, 4, 5, 6, 7, 8 Ic 1 PERFORMANCE CHECKLIST 1 STANDARD I NIA I SAT I UN I 1 SAT
- 1. Verffy power adjust potentiometers are set at zero. Verified power adjust potentiometers set to zero on C26 (if not already at I I POSITIVE CUE:
Power adjust ootentiometers for M55AiB are set at zero on zero used knurled &b on power adjust potentiometers on C26 and turned to the left and set at zero using HS-7472 and HS-7473).
- 2. Turn hydrogen recombiners M55A and M55B on. Turned on hydrogen recombiners C M55A and M55B using HS-7470 and II POSITIVE CUE:
MSSA/B red lights ON
/ I I d NEGATIX CUE:
M55- green lights ON.
- 3. Select thermocouple #I, 2 or 3 to input to recombiner Thermocouple #I, 2 or 3 selected to temperature mdicators TI-2300 and TI-2301. input to TI-2300 and TI-2301 using handswitches HS-7474 and HS-7475 POSITIVE CUE: on C26.
Thermocouple #I, 2 or 3 selected as desired to input to TI-2300 and TI-2301.
- 4. Increase power to -5 KW.
/.
L clockwise until power on JI-1000 and POSITIVE CUE: JI-1001 on C26 indicated-5 KW.
Power on JI-1000 and J1-1001 indicates 5KW.
1 8
INSTRUCTOR NOTE:
Inform examinee that ten minutes have elapsed after one minute at 10 KW.
- 5. Slowly increase power to 10 KW and record initial time.
C power adjust potentiometers on C26.
POSITIVE CUE: Recorded time 10 KW was achieved. -
Power is at 10 KW on JI-1000 and JI-1001 INSTRUCTOR NOTE:
Inform examinee that taking data every 30 minutes on Attachment E will be simulated.
Inform examinee that ten minutes have elapsed after achieving 10 KW.
Inform examinee that five minutes have elapsed after one minute at 20 KW.
1
- 6. Slowly increase power to 20 KW on M55B and hold for Increased power on M55B to -20 C 5 minutes. KW using power adjust potentiometer on C26. - - -
POSITIVE CUE:
Power at 20 KW on JI-1001.
Page 4 of 5 TUOI NUMBER: AIJPM-RO-HYDO3 Ic 1 PERFORMANCE CHECKLIST 1 STANDARD 1 NIA I SAT I UN 1 SAT
- 7. Determine power required from Attachment B based on Determined Recombiner power to be C containment pressure (26.0 psia and 120°F Pre-LOCA from 68.0 to 70.0 KW using containment temperature). Attachment B of 1104.031. - - -
- 8. Slowly increase power to 68.0-70.0 KW range. Power increased to 68.0 to 70.0 KW C range using power adjust POSITIVE CUE: potentiometer on C26. - - -
Hydrogen concentration dropping on QI-7459 and M55B maintaining power at determined value.
NEGATIVE CUE:
Hydrogen concentration rising or steady on QI-7459.
I END
TUOl NUMBER: AIJPM-RO-HYD03 INITIAL CONDITIONS:
A LOCA has occurred.
Containment hydrogen concentration is 2.5%.
Both hydrogen recombiners are shutdown.
Containment pressure is 26.0 psia.
Pre-LOCA containment temperature was 120°F.
INITIATING CUE:
The CRSISM directs you to place both hydrogen recombiners (M55AIB) in standby and then place M55B in operation.
Note: Your task is complete when the power you have determinedfor recombiner operation is achieved
7 ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLEAR ONE TITLE CONTAINMENT HYDROGEN CONTROL DOCUMENT NO CHANGE NO 1104.031 014-03-0 WORK PLAN EXP DATE TC EXP DATE NIA NIA SAFEN-RELATED IPTE SET # BYES ON0 DYES @NO .
TEMP ALT OYES @NO When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Distractionllnterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShiftILast Shift Knowledge Peer Pressure Procedures ChangeIOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME FORM TITLE: FORM NO. CHANGE NO.
VERIFICATION COVER SHEET 1000.006A 050-00-0
PROC.M'ORK PLAN NO. PROCEDUREM'ORK PLAN TITLE: PAGE: 8 of 52 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 014-030 CAUTION Hydrogen recombiners should be placed in operation following a LOCA as soon as time permits and must be in operation before hydrogen concentration reaches 3.0%.
8.0 Placing Hydrogen Recombiner (M55A or M55B) in Operation NOTE Both M55A and M55B are placed in standby, then either may be placed in I operation. I 8.1 Place both MSIA and M55B in standby as follows 8.1.1 Place M55A in standby by performing the following:
A. Verify Power Adjust Potentiometer is set at zero for M55A.
- 8. Start M55A by placing HS-7470 in ON C. Select thermocouple #1, 2, or 3 (HS-7474)to input to M55A Temperature (TI-2300).
D. Slowly turn power adjust potentiometers clockwise to raise power to 5 KW as indicated on M55A Power (JI-1000).
E. Slowly raise power to 10 KW
- 1. Record initial time at 10 KW:
- 2. Maintain 10 KW output for standby service.
8.1.2 Place M55B in standby by performing the following:
A. Verify Power Adjust Potentiometer is set at zero for M55B.
B. Start M55B by placing 853-7471 in ON C. Select thermocouple #1, 2, or 3 (HS-7475) to input to M55B Temperature (TI-2301).
D. Slowly turn power adjust potentiometers clockwise to raise power to 5 KW as indicated on M55B Power (31-1001).
E. Slowly raise power to 10 KW.
- 1. Record initial time at 10 KW:
- 2. Maintain 10 KW output for standby service
PROC.NIIORK PLAN NO. PROCEDUREIWORK PLAN TITLE: PAGE: 9 0f 52 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 014-03-0 NOTE Following a LOCA, M55A or M55B must be in operation before Hz concentration reaches 3.0% as indicated on the highest reading H, analyzer.
8.2 Place recombiners in operation as follows:
8.2.1 Place M55A in service by performing the following:
A. During heatup, monitor and record all three thermocouple temperatures every 30 minutes on Attachment D.
B. Verify M55A has been at 10 KW for at least 10 minutes C. Slowly raise power to 20 KW AND hold for 5 minutes.
D. Determine power required from Recombiner Power (M-55Al Versus Containment Pressure (Attachment B of this procedure) based on containment pressure.
11 KW setting I CAUTION Excessive power and temperature may cause heater failure. I
- 2) Slowly raise power to the value determined above E. Verify proper recombiner operation by observing the following:
NOTE Hydrogen concentration reduction is the long-term, primary method of verification.
H, concentration reduction shall be used regardless of recombiner power or temperature indication as the verification of proper recombiner operation.
Hydrogen concentration stable or dropping at
% Hydrogen (QI-7457 and QI-74591 .
Recombiner maintaining power at value determined
PROC.PNORK PLAN N
O. PROCEDURE
iWORK PLAN TITLE: PAGE: 10 of52 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 014-03-0 NOTE Thermocouples are non-Q and will not be reliable indicators in a post-LOCA environment.
Recombiner temperature can aid in trending recombiner operation. The following steps are provided as guidelines.
Recombiner temperature may be plotted on Attachment C for verifying I
thermocouple operation and estimating time when recombination temperature will be reached.
F. Establish validity of temperature indication by comparing AT between thermocouples.
- 1. IF all three thermocouples fall within a 6O0F band, THEN average the three temperatures.
- 2. IF no two thermocouples are within 60°F of each other, THEN thermocouples should be considered inaccurate.
- 3. IF difference of the three temperatures >60°F, two temperatures are within 6O0F, THEN average the closest two.
G. Monitor for indication that recombiner operating temperature of 1225OF has been reached.
NOTE Valid thermocouples show a ramp rise in temperature with H, concentration ~ 2 % .
indicating recombination temperature has been reached and recombination is taking place.
H. hydrogen concentration is ,2%,
THEN monitor for a ramp rise in temperature I. After four hours of full power operation, log data in Attachment D once per hour.
PROC.MORK PLAN NO. PROCEDUREMORK PLAN TITLE: PAGE: 11 of 52 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 014-03-0 8.2.2 Place M55B in service by performing the following:
A. During heatup, monitor and record all three thermocouple temperatures every 30 minutes on Attachment E.
B. Verify M55B has been at 10 KW for at least 10 minutes.
C. Slowly raise power to 20 KW AND hold for 5 minutes D. Determine power required from Recombiner Power (M-558)
Versus Containment Pressure (Attachment B of this procedure) based on containment pressure.
- 1) KW setting I CAUTION Excessive power and temperature may cause heater failure. I
- 2) Slowly raise power to the value determined above E. Verify proper recombiner operation by observing the following:
NOTE Hydrogen concentration reduction is the long-term, primary method of verification.
H, concentration reduction shall be used regardless of recombiner power or temperature indication as the verification of proper recombiner operation.
Hydrogen concentration stable or dropping at
% Hydrogen (QI-7457 and 01-7459).
Recombiner maintaining power at value determined
PROC.IWORK PLAN NO. PROCEDUREIWORK PLAN TIRE: PAGE: 12of 52 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 014-03-0 NOTE Thermocouples are non-Q and will not be reliable indicators in a post-LOCA environment.
Recombiner temperature can aid in trending recombiner operation. The following steps are provided as guidelines.
Recombiner temperature may be plotted on Attachment C for verifying I
thermocouple operation and estimating time when recombination temperature will be reached.
F. Establish validity of temperature indication by comparing AT between thermocouples.
- 1. F all three thermocouples fall within a 60°F band, THEN average the three temperatures.
- 2. 2 no two thermocouples are within 60°F of each other, THEN thermocouples should be considered inaccurate.
- 3. IF difference of the three temperatures >60°F, two temperatures are within 60°F.
THEN average the closest two.
G. Monitor for indication that recombiner operating temperature of 1225°F has been reached.
NOTE Valid thermocouples show a ramp rise in temperature with H, concentration 22%.
indicating recombination temperature has been reached and recombination is taking place.
H. IF hydrogen concentration is 12%,
THEN monitor for a ramp rise in temperature.
I. After four hours of full power operation, log data in Attachment E once per hour.
8.2.3 -
I F proper power setting causes average valid temperature to exceed 1450°F OR in-service recombiner has insufficient capacity, THEN place standby recombiner in service.
8.2.4 Do NOT lower recombiner power based on extreme temperature Maintain power until standby recombiner is heated to operating temperature.
8.3 Monitor Hydrogen Samplers (C178 and C179) to verify recombiner(s) maintaining or lowering hydrogen concentration.
PROC.NVORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 13of52 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 014-03-0 I CAUTION Excessive power and temperature may cause heater failure.
3 NOTE I A power change of 4 KW will change temperature approximately 75OF I
8.3.1 -IF H, concentration has risen by >0.5% in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />
-OR H, concentration >3.0%,
THEN raise recombiner power setting by 4 KW above the previous setting.
NOTE A change in containment pressure will require an adjustment to recombiner I power. I 8.4 Monitor containment pressure 8.4.1 WHEN pressure changes, THEN adjust recombiner power to new value from Attachment B.
8.5 -
WHEN no longer required, THEN secure Hydrogen Recombiner as follows:
8.5.1 Secure M55A as follows:
A. Lower power to zero B. Secure M55A by placing HS-7470 to OFF C. Leave a thermocouple selected as input to M55A Temperature (TI-2300).
8.5.2 Secure M55B as follows:
A. Lower power to zero B. Secure M55B by placing HS-7471 to OFF C. Leave a thermocouple selected as input to M55B Temperature (TI-23011.
PROC.WORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 18of 52 1104.031 CONTAINMENT HYDROGEN CONTROL CHANGE: 014.034 ATTACHMENT B Page 2 of 2 RECOMBINER POWER (M-556)
VERSUS CONTAINMENT PRESSURE 45 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 Post-LOCA Containment Pressure (0.2 psia increments)
Note: Use pre- LOCA average Reactor Building Temperature from SPDS (TAVRB1) from history file if available. Otherwise use logs.
Page 1of 5 JOB PERFORMANCE MEASURE Unit: 1 Rev # 4 Date:
TUOI NUMBER: AlJPM-RO-ED008 SystemlDuty Area: Electrical Distribution Task: Shift buses Al, A2, H1, H2 from S t m p One to Unit Aux Transformer JA# ANO1-RO-ELECD-NORM-25 KA Value RO 3.1 SRO 3.1 KA Reference 062 A4.07 Approved For Administration To: RO El SRO Task Location: Inside CR: Ed Outside CR: Both:
Suggested Testing Environment And Method (Perform Or Simulate #):
Plant Site: Simulator#: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Simulator #: Plant Site: Lab Testing Method: Simulate: Perfom:
Approximate Completion Time In Minutes: 10 Minutes Reference(S): 1107.001 Chg. 060-19-0 Examinee's Name: SSN:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained m this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time Signed # Date:
- TQ-202 attachment 9 is complete and on file for performance of this JPM for the current Reactor core configufdtion.
Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
TUOI NUMBER: AlJPM-RO-ED008 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMIEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee JPM ATTI& TASK CONDITIONS:
Plant is at 20-40% wwer and readv to transfer plant auxiliaries to the Unit Aux Transformer. The Unit Auxiliw Transformer is available and all breaker controls are in Remote." SEE SETUP BELOW.
TASK STANDARD:
Plant auxiliaries (Al, A2, HI. HZ) are being powered from the Unit Auxiliary Transformer. This is a faulted JPM, the ouerator must manuaUv trip one of the power supplies to A1 bus.
TASK PERFORMANCE AIDS:
Svnch-switch handle. 1107.001 Step 8.2 Simulator setuo:
The fanited breaker for this JPM w~llbe implemented by use of an override. Prior to providing the initial conditions for this JPM insert the following:
Override DI-A112R;False This will cause the SUI feeder breaker to bus A1 to fail to open when the Unit Aux feeder handswitch is released aRer being closed (the override defeats the return-to-normal for breaker A-112, Unit A m to Al).
TUOI NUMBER: AIJPM-RO-ED008 INITIATING CUE: The CRSISM directs you to transfer plant auxiliaries from Startup One Transformer to the Unit Auxiliary Transformer.
CRlTICAL ELEMENTS (c): LU C I PERFORMANCE CNECKLIST I STANDARD I NIA I SAT I UN I 1 SAT 1 INSTRUCTOR NOTE: Thts 1s a faulted JPM the Startup One to A1 breaker w11 not automatically open after the Umt AUXto A1 breaker 1s closed, the operator must manually tnp one of the feeder breakers to A1 Steps 1through 5 will be completed four times for four buses.
- 1. On C10, place Synchronize switch to ON for the Unit T m e d ON Synchronize switcb for C Aux Feeder Breaker that is to be closed. correct breaker.
POSITIVE CUE:
Synchronize switcb ON
- 2. Verify synchroscope is at I2 o'clock. Verified sycnhroscope stopped near the 12 o'clock position,
- 3. On C10, close Unit Aux Feeder breaker. Allow control Closed Unit Aux Feeder Breaker and C switch to return to normal-after-close position. allowed control switch to return to - -
normal-after-close position.
POSITIVE CUE:
Unit Aux Feeder Breaker closed.
L
- 4. On C10, tnrn Synchronize switch OFF. Tnmed Synchronize switch OFF.
POSITIVE CUE:
Synchronize switch OW.
I I I I I INSTRUCTOR NOTE: When examinee closes Unit Aux breaker on A1 bus, the SU #I feeder breaker for A1 will not open.
verify that the SU1 Feeder Breaker opens. Verified that the SU1 Feeder Breaker Opened.
POSITIVE CUE: - - -
SU1 feeder breaker opened.
NEGATIVE CUE:
Al SU1 breaker did not open, Unit Aux and SUI feeder breakers to A1 are closed.
- 6. If the SU1 breaker does not immediately open, trip it. Tripped (to open) the SU1 feeder C breaker to A1 bus (A-113).
POSITIVE CUE: - - -
SU1 to A1 breaker is open.
- 7. Place the open breaker's controt switcb in nod-after- Placed the open breaker's control open. switch in the nod-afterapen position.
Page 4 of 5 TUOI NUMJ3ER: AIJPM-RO-ED008 C PERFORMANCE CHECKLIST STANDARD NIA SAT UN SAT
- 8. Venfy Startnp XFMRS Pref Transfer selector switch is Verified Startup XlWRS Pref in the desired position. Transfer selector switch is in the desired position (to SUI).
- buses remain above 6010V.
9 Verified proper voltages on Al, A2, H1 and H2.
- 10. Contact relay group to perform visual verification of Contacted relay group.
contact closure of Sync Check Relays.
END
TUOI NUMBER: AlJPM-RO-ED008 INITIAL CONDITIONS:
Plant is at 20-40% power and ready to transfer plant auxiliaries to the Unit Aux Transformer.
The Unit Auxiliary Transformer is available and all breaker controls are in "Remote."
INITIATING CUE:
The CRSISM directs you to transfer plant auxiliaries fiom Startup One Transformer to the Unit Auxiliary Transformer.
ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLEAR ONE TITLE ELECTRICAL SYSTEM OPERATIONS DOCUMENT NO CHANGE NO 1107.001 060-194 WORK PLAN EXP DATE TC EXP DATE NfA NIA SAFEPI-RELATED IPTE SET # BYES ON0 BYES ON0 TEMP ALT mYES O N 0 When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Distraction/lnterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShiWLast Shift Knowledge Peer Pressure Procedures ChangelOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME FORM TITLE: FORM NO. CHANGE NO.
VERIFICATION COVER SHEET 1000.006A 050-009
PROC.JWORK PLAN NO. PROCEDUREJWORK PLAN TITLE:
PAGE: 16 of 276 1107.001 ELECTRICAL SYSTEM OPERATIONS CHANGE: 060-19-0 8.1.4 IF RCS is S200°F
@ it is desired to remove SU 2 Transformer Feeder Breakers to A2, HI, H2 control switches from PULL-TO-LOCK, THEN perform the following:
NOTE Lamps for Load Shed circuits only indicate power available to the circuit. Test switches for defeating this feature do not cause the lamps to go out.
SU2 Load Shed feature is defeated by opening Switch G located beneath the cover of TS-1 111 Test SW and TS-1 211 Test SW, at A-111 and A-211, respectively. The switch cover cannot be installed with Switch G open.
A. SU 2 Transformer load shed circuit operable as follows:
Lamp on at Startup XFMR #2 Feed to A1 (A-111) illuminated.
Lamp on at Startup XFMR #2 Feed to H1 (H-13)
. illuminated.
Cover installed on Cover installed on TS-1 111 Test SW at A-111.
TS-1 211 Test SW at A-211.
B. UNLESS allowed by Design Engineering Evaluation, verify Unit 2 has SU 2 Transformer feeder breakers in PULL-TO-LOCK.
C. Inform Unit 2 of intent to remove Unit 1 feeder breakers from SU 2 from PULL-TO-LOCK.
D. Remove SU 2 feeder breakers to A2, HI, and H2 as desired from PULL-TO-LOCK.
8.1.5 To transfer loads to SU 2 perform the appropriate section of this procedure.
8.2 Transferring Buses From SU 1 to Unit Aux 8.2.1 Verify breakers to be operated are in the remote position.
8.2.2 Verify Unit Aux Transformer is operable.
8.2.3 For Unit Aux Feeder Breaker that is to be closed, turn Synchronize switch on.
PROC.MlORK PLAN NO. PROCEDUREMlORK PLAN TITLE:
PAGE: 17 Of 276 1107.001 ELECTRICAL SYSTEM OPERATIONS CHANGE: 060-19-0 8.2.4 Verifv . svnchrosco~e
. between 11 and 1 o'clock (4.3.4)
CAUTION High c i r c u l a t i n g c u r r e n t s may t r i p bus lockout r e l a y i f both feeder breakers remain closed.
8.2.5 Close Unit Aux Feeder breaker. Allow control switch to return to NORMAL-AFTER-CLOSEposition.
NOTE Svnchronize switch must be off to verify feeder breaker opens. With 1 Synchronize switch on, red light for feeder breaker position goes out even if breaker does not trip.
8.2.6 Turn Synchronize switch off 8.2.7 Verify that the SU 1 Feeder Breaker opens A. _IPI the SU 1 breaker does immediately open, trip it.
B. IF the SU 1 breaker w i l l NOT t r i p ,
THEN reopen t h e AND delay power Unit Aux Feeder breaker e s c a l a t i o n u n t i l the problem i s resolved.
- 1. n e i t h e r SU 1 breaker nor Unit Aux breaker w i l l open, THEN dispatch an operator t o manually t r i p the Unit Aux Feeder breaker AND delay power e s c a l a t i o n u n t i l t h e problem i s resolved.
- 2. Initiate maintenance action for repairs 8.2.8 Place the open breaker's control switch in NORMAL-AFTER-OPEN.
8.2.9 Repeat steps until all buses are on Unit Aux 8.2.10 Verify Startup XFMRS Pref Transfer selector switch is in the desired position.
8.2.11 Verify 4160V buses remain above 3640V and 6900V buses remain above 6010V.
8.2.12 Contact Relay Group to perform visual verification of contact closure of Sync Check Relays.
JOB PERFORMANCE MEASURE Unit: 1 Rev # 0 Date:
TUOI NUMBER: AIJPM-RO-ARM01 SystemDuty Area: Area Radiation Monitor System Task: Respond to Area Radiation Monitor alann JA# ANOl-WCO-RMS-SURV-7 KA ValueRO 3.0 SRO 3.3 KA Reference 072 A4.01 Approved For Administration To: RO El SRO Task Location: Inside CR:
- Outside CR: a Both: 0 Suggested Testing Environment And Method (Perform Or Simulate #):
Plant Site: Simulator#: Perform Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Simulator #: Plant Site: Lab Testing Method: Simulate: Perform:
Approximate Completion Time In Minutes: 20 Minutes Reference(s): 1305.001Chg. 014-15-0 Examinee's Name: SSN:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Time Stop Time Total Time Signed # Date:
- TO-202 attachment 9 is comulete and on file for uerformance of this JPM for the current Reactor core confimtion.
Signitwe indicates this JPM has been compared to'its applicable procedure by a qualified individual (not the &minee) and is cnrrent with that revision.
TUOI NUMBER: AIJPM-RO-ARMOl THE EXAMINER SHALL REVlEW TI-IE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist System Walkthrough" porlion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS:
Annunciator KlO-B1. AREA MONITOR RADIATION HI, has alarmed. A check of C-25 Bav 3 shows RI-8006. Radio Chem Lab, Warning light is on and is reading 1.5 m R k . Radiation Protection has snrveved the area and reported to the CRS.
TASK STANDARD:
RI-8006 Radio Chem Lab warning setpoint adjusted to 1.6 to 2.5 m R h .
TASK PEREORMANCE AIDS:
1305.001. supulement 6
TUOI NUMBER: A13PM-RO-ARM01 INITIATING CUE: The CRS directs you to adjust the warning setpoint for RI-8006 to 2.0 mRfhr.
CRITICAL ELEMENTS (c):
C PERFORMANCE CIIECKLIST STANDARD NIA SAT UN
. .- - . L-- . I . L.-
=
EXAMINER NO'I'E: Wtlcn Wdinn. pklces ;11annsettilig snitch ln tlic WARNING position. Uien i i ~ o n nlriiincc the indicator is L re;td~ngI tnmlr.
- 1. On RI-8006, place darm setting switch in the On C25 Bay 3, placed RI-8006 alarm WARNING position and observe warning setpoint vdne setting sw~tchin WARNING.
on indicator. Observed warning setpoint value. - - -
I / POSITIVE CUE:
I .IRI-8006 i11ann sctting s\\itch in \VARNlNG.
I I
I 1 I
-EXAMINER NOTE lnforln mince RI-XOU6 indicator 1s rcading 1.5 tnWhr b;ickground J c! 2. Slide RI-8006 drawer out. On RI-8006, depressed handle release buttons and pulled drawer out.
I I POSITIVE CUE:
RI-8006 drawer out
- 3. Hold alarm setting switch in the WARNING position I On Ri-8006 drawer, held alarm I-I-C and adjust warning potentiometer to 2.0 m R k . setting switch in the WARNING - - -
position and adjusted warning POSITIVE CUE: potentiometer to 2.0 mR/hr.
Warning potentiometer set to 2.0 mWhr.
/ 1 4. Slide RI-8006 drawer int. On RI-8006, slid drawer in.
POSITIVE CUE: - - -
RI-8006 drawer inserted, 1 I 5. Reset Waming d m . On RI-8006, turned ALARM RESET/CIIECK SOURCE swttch to I I POSITIVE CUE:
Warning alarm clear.
- 6. Record as-left setpoint vdne in section 3.0 ALARM RESET.
In section 3.0, recorded value of 2.0 C mR/hr in warning as-left setpoint space for RI-8006. - - -
... -7 I I
EXAMINER N O E : \\hen trdinec places a l m i selling s\\iich in tlic HIGH position. then inforin trdirice thc indicator is reading 4 rttK/ltr
......... -. . .. .. ... .... ... j
Page 4 of 5 TUOI NUMBER: AlJPM-RO-ARM0 1 C PERFORMANCE CHECKLIST STANDARD N/A SAT
- 7. On RI-8006, place alarm setting switch in the HIGH On C25 Bay 3, placed RI-8006 alarm position and observe high alarm setpoint value on setting switch in HIGH. Observed indicator. high setpoint value. - -
POSITIVE CUE:
RI-8006 alarm setting switch in high.
__._ .--I
.... - -1 . -. . . L L .. I . -
EXAMINER NOT: Infonil trainee that no adjustmcnr is nacssin? for the HIGH sctpoinl.
- 8. Record as-left setpoint value in section 3.0, In section 3.0, recorded value of 4.0 mR/hr for the high as-left setpoint for RI-8006. - - -
TUOI NUMBER: AIJPM-RO-ARM01 INITIAL CONDITIONS:
Annunciator KIO-B 1, AREA MONITOR RADIATION HI, has alarmed A check of C-25 Bay 3 shows RI-8006, Radio Chem Lab, Warning light is on and is reading 1 5 mR/hr Radiation Protection has sulveyed the area and reported to the CRS INITIATING CUE:
The CRS directs you to adjust the warning setpoint for RI-8006 to 2 0 mR/hr
Distractionllnterruption Questioning Attitude Multiple Tasks Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShiftlLast Shift Peer Pressure Procedures ChangelOff Normal Job Briefing Physical Environment I VERIFICATION COVER SHEET
PROC.MORK PLAN NO. PROCEDUREMIORK PLAN TITLE: PAGE: 40 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-15-0 SUPPLEMENT 6 Page 1 of 11 AREA RADIATION MONITOR MONTHLY ALARM CHECK This check verifies high alarm setpoints on Unit 1 Area Monitors and checks or sets the warning alarm setpoint to provide a meaningful alarm. This check records the high alarm setpoint for Unit 1 CR Supply Vent Rad Detectors ZRITS-8001A AND ZRITS-8001B.
1.0 INITIAL CONDITIONS INITIALS 1.1 Check purpose of this test Regularly scheduled monthly test
__ Other (describe in section 4.0) 1.2 Observe the following precautions: -
The warning alarm on Control Room Area Monitor (RI-8001) is interlocked with the control room isolation system.
NOTE Control Room Area Monitor does not have audible alarm.
The hi alarm of all area monitors is interlocked to give audible and visual remote alarms at the location of each monitor.
The alarm setting knob will cause RAD MONITOR IN TEST annunciator (K-10-F1)to alarm. It will not cause a warning or hi alarm interlock to actuate.
The energizing of the check source will cause automatic interlocks of the alarm and warning to actuate if the setpoint is exceeded. Do not energize the check source during the performance of this test.
IF elevated background radiation levels exceed the Maximum Normal Warning setpoint listed in section 3.0, THEN the warning setpoint may be adjusted above the Maximum Normal setpoints by performance of this supplement. Documentation of reason for elevated radiation levels will he recorded in section 4.0.
The warning setpoint shall he set below the Minimum setpoint listed in Section 3.0.
Except for brief periods during evolutions such as Dry Fuel movement, the high alarm setpoint shall NOT exceed Maximum High Alarm Setpoint listed in section_@.
PROC.MIORK PLAN NO. PROCEDURElWORK PLAN TITLE: PAGE: 41 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-155 SUPPLEMENT 6 Page 2 of 11 2.0 PROCEDURE 2.1 Perform one of the following: N/A method not used.
IF performing the monthly test, THEN complete steps 2.2 for Control Room Rrea Radiation Monitor (RE-8001)and step 2.3 for all other area monitors listed in Section 3.0.
IF performing requirement, this supplement for other than monthly -
THEN perform only the area monitor(s) determined by the Shift Manager/CRS and N/A all others.
2.2 Control Room Area Radiation Monitor (RE-8001)
CAUTION The warning alarm on Control Room Monitor (RI-8001) is interlocked with the control room isolation system. Energizing of the check source will cause automatic actuation of the Control Room isolation system when the warning alarm setpoint is reached.
2.2.1 Place Alarm Setting switch in the WARNING position and observe warning setpoint value on RI-8001 is 51 MR/HR.
NOTE Warning setpoints should be adjusted as necessary to a value high enough to preclude warninq actuations due to electrical noise deflections but low I ;nough to detec; rising radiation levels as early as possible. I 2.2.2 -
IF RI-8001 background is such that the warning setpoint needs to be adjusted, THEN adjust the setpoint as follows.
A. Notify Unit 2 to place CONTROL ROOM DAMPER HANDSWITCH (2HS-8685-2)on 2C33-2 in the CLOSE position.
- 8. Isolate Unit 1 Control Room by placing Channel A and Channel B Control Room Isolation handswitches in the MAN position.
C. Verify Actuation Control Room Isolation (K16-82) in alarm indicating isolation of control room.
PROC.MIORK PLAN NO. PROCEDUREMIORK PLAN TITLE: PAGE: 42 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-15-0 SUPPLEMENT 6 Page 3 of 11 D. Slide Area Monitor drawer out to gain access to Alarm Setting potentiometers.
E. While holding the Alarm Setting switch in -
the WARNING position, adjust the warning potentiometer to the desired setpoint but not less than 1 XR/ER.
F. Slide Area Monitor drawer back to the -
normal position and secure.
G. Reset alarms if applicable. -
H. Place Channel A and Channel B Control Room Isolation handswitches in the AUTO position.
I. At C141 in the computer room, depress PB-1 Unit One Radiation Reset pushbutton.
J. At C141A in the computer room, depress PB-2 System Trip Reset pushbutton.
K. At C141B in the computer room, depress PB-2 System Trip Reset pushbutton.
L. Verify all Control Room Isolation trips reset and K16-B2 is clear.
M. Notify Unit 2 to place 2HS-8685-2 on 2C33-2 in the AUTO position.
2.2.3 Record As-Left Setpoint for RI-8001 in section 3.0.
2.2.4 Place the Alarm Setting switch in the HIGH position and observe the high alarm setpoint on RI-8001.
2.2.5 Release switch and record As-Left setpoint in section 3.0.
2.2.6 Use DBM function of PMS computer, adjust Area Monitor RI-8001 alarm setpoint to be in accordance with as-left data of this supplement.
PROC.MIORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 43 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-155 SUPPLEMENT 6 Page 4 of 11 2.3 For each remaining area monitor perform the following:
1 -
NOTE 1 i Monitors may be tested in any order. Test steps shall be followed in order.
Warning setpoints should be adjusted as necessary to a value high enough to preclude warning actuations due to electrical noise deflections but low enough to detect rising radiation levels as early as possible.
2.3.1 Place Alarm Setting switch in the WARNING position and observe warning setpoint value on indicator.
2.3.2 -
IF the background for the monitor is such that the warning setpoint needs to be adjusted, THEN adjust the setpoint as follows.
A. Slide Area Monitor drawer out to gain access to Alarm Setting potentiometers B. While holding the Alarm Setting switch in the WARNING position, adjust the warning potentiometer to the desired setpoint.
C. Slide Area Monitor drawer back to the normal position and secure.
D. Reset alarms if applicable 2.3.3 Record As-Left Setpoint for each monitor in section 3.0.
-NOTE Except for brief periods during evolutions such as Dry Fuel movement, the high alarm setpoint shall exceed Maximum High Alarm Setpoint listed in Section 3.0. The high alarm setpoint should be adjusted slightly below or equal to the Maximum High Alarm Setpoint listed in Section 3.0.
2.3.4 Place the Alarm Setting switch in the HIGH -
position and observe the high alarm setpoint on indicator.
PROC.IWORK PLAN NO. PROCEDUREIWORK PLAN TITLE: PAGE: 44 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014.154 SUPPLEMENT 6 Page 5 of 11 2.3.5 -
IF Alarm setpoint exceeds max allowable value or if high alarm setpoint must be adjusted for any reason, adjust the setpoint as follows:
A. Slide Area Monitor drawer out to gain access to Alarm Setting potentiometers.
B. While holding the Alarm Setting switch in the HIGH position, adjust the HIGH potentiometer to the desired setpoint.
C. Slide Area Monitor drawer back to the normal position and secure.
D. Reset alarms if applicable.
E. Inform SM/CRS of any abnormal findings.
2.3.6 Record As-Left Setpoint in section 3.0. -
2.3.7 Use "DBM" function of PMS computer, adjust Area Monitor alarm setpoints to be in accordance with as-left data of this supplement.
2.4 Check Unit 1 CR Supply Vent Rad Detector 2RITS-8001A high alarm setpoint as follows.
2.4.1 At 2RITS-8001A, press MODE to display high alarm setpoint and record in section 3.0.
2.4.2 At PMS computer, check 2RITS-8001A High Alarm -
Static Point (C02-7) indicates same value as monitor setpoint. Otherwise, using PMS "CREVSA" display, change point to display current high alarm setpoint.
2.4.3 Using DBM function on PMS computer, check alarm -
setting for (R8001AMG) with Low setpoint at 21.2 and High setpoint at 21.8.
PROC.WORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 45 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-15-0 SUPPLEMENT 6 Page 6 of 11 2.5 Check Unit 1 CR Supply Vent Rad Detector 2RITS-8001B high alarm setpoint as follows.
2.5.1 At 2RITS-8001B, press MODE to display high alarm setpoint and record in section 3.0.
2.5.2 At PMS computer, check 2RITS-80018 High Alarm -
Static Point (C03-7) indicates same value as monitor setpoint. Otherwise, using PMS 'CREVSB" display, change point to display current high alarm setpoint.
2.5.3 Using "DBM" function on PMS computer, check alarm setting for (R8001BMG) with Low setpoint at 21.2 and High setpoint at 51.8.
PROC.WORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 46 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-15-0 SUPPLEMENT 6 Page 7 of 11 This is based on the Control Room being designed for continuous occupancy at a maximum of 5 Rem for the duration of a maximum (4.3.1) hypothetical accident (30 days continuous occupancy) according to ANO-1 (4.3.2) Note 1 SAR. It was calculated as follows:
5 X 10' mR 5 7 mR/m (30 days) (24 hr/day)
Note 2 This is based on the design value for this area during normal operation (assuming 1% failed fuel) according to ANO-1 SAR.
During refueling shutdown, set the alarm sufficiently above the backgLound reading to minimize constant alarming. 1f alarm setpoint must exceed 100 mRjHR, ensure HP is notified and thearea properly posted.
Establish the background for this meter and set the warning lower than Note 4 the alarm setpoint but sufficiently above the background reading to minimize constant alarming.
Note 5 Based upon lMPC XE-133. (Calc 91-E-0067-01) 3.0 ACCEPTANCE CRITERIA 3.1 Compare the As-Left Setpoint to the Maximum Normal Setpoint -
and the As-Left High Alarm Setpoint to the Max High Alarm Setpoint.
NOTE Warning alarm setpoints should be adjusted as necessary to a value high enough to preclude any warning actuations due to electrical noise deflections but low enough to detect rising radiation levels as early as
. possible.
High alarm setpoints are based, with the noted exceptions, on minimizing spurious alarms due to transient radiation level rises but low enough to provide early detection of abnormal radiological conditions in the area.
I WARNING SETTING I ALARM SETTING I I I I I IS I AS-LEFT /
AS-LEFT SETPOINT MONITOR SETPOINT AS-LEFT INDICATOR HIGH NUMBER/ MINIMUM AS-LEFT ALAIRM DESCRIPTION SETPOINT SETPOINT SETPOINT 14.3.1) RI-8001 7 mR/HR CONTROL ROOM 1 mR/m (2) YES NO YES NO NOTE: NUMBERS IN PARENTHESES REPE ! TO NOTES AT TOP OP HIS PAGE.
(continued next page)
PROC.lWORK PLAN NO. PROCEDURElWORK PLAN TITLE: PAGE: 47 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-15-0 SUPPLEMENT 6 Page 8 of 11 3.0 (Continued)
WARNING SETTING ALARM SETTING IS AS-LEFT HIGH IS ALARM AS - LEFT SETPOINT MONITOR SETPOINT AS-LEFT MAXIMUM 5 INDICATOR MAXIMUM 5 MAX HIGH HIGH HIGH NUMBER/ MINIMUM AS-LEFT NORMAL NORMAL ALARM ALARM ALARM DESCRIPTION SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT RI-8002 1 mR/HR RELAY ROOM 1 mR/HR (2) YES NO 2 mR/HR YES NO RI-8003 1 mR/HR MACHINE SHOP 1 mR/HR (21 YES NO 2 mR/HR YES NO RI-8004 OUTSIDE STAIRWAY EL 317' 1 ~R/HR lo ~ R / H R YES NO 20 ~ R / H R YES NO RI-8005 SAMPLE RM 2.5 7.5 VESTIBULE 1 mR/HR mR/HR YES NO mR/HR YES NO RI-6006 RADIOCHEM. 2.5 7.5 LAB 1 ~R/HR ~R/HR YES NO ~R/HR YES NO RI-8007 OUTSIDE STAIRWAY 2.5 7.5 EL 369' 1 mR/HR mR/HR YES NO mR/HR YES NO RI-8008 DECON RM EL 386' 1 mR/HR 10 m / H R YES NO 20 mR/HR YES NO RI-8009 SF POOL I ~R/HR 10 ~ R / H R YES NO 20 ~ R / H R YES NO RI-8010 CA AREA 1 mR/HR 2.5 EL 386' 1 mR/HR (2) YES NO mR/HR YES NO RI-6011 OUTSIDE STAIRWAY EL 335' 1 mR/HR 10 mR/HR YES NO 20 mR/HR YES NO NOTE: NUXBERS I N PARENTBESES REPER TO NOTES ON PAGE 7 OP T H I S SUPPLEMENT.
(continued next page)
PROC.IWORK PLAN NO. PROCEDUREMORK PLAN TITLE: PAGE: 48 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-154 SUPPLEMENT 6 Page 9 of 11 WARNING SETTING ALARM SETTING IS AS-LEFT HIGH IS ALARM AS-LEFT SETPOINT MONITOR SETPOINT AS-LEFT MAXIMUM 5 MAX INDICATOR MAXIMUM 5 MAX HIGH HIGH HIGH NUMBER/ MINIMUM AS-LEFT NORMAL NORMAL ALARM ALARM ALARM DESCRIPTION SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT RI-8012 PIPING AREA I BY ELEV EL 335' 1 mR/HR 10 mR/HR YES NO 20 mR/HR YES NO RI-8013 PIPING AREA I1 BY EMERG 2.5 7.5 FEED PMP 1 ~R/HR ~R/HR YES NO ~R/HR YES NO RI-8014 STAIRWAY I 1 I I I I I I VESTIBULE I .3 ~ R / H R I I 10 ~ R / H RI YES NO I / I 20 ~ R / H R YES NO RI-8015 I 1 I 1 mR/HR / I 1 1 COND. DEMIN 1 ~R/HR (2) YES NO 2 ~ R / H R YES NO RI-8016 SPENT FUEL FILTERS AREA 1 mR/HR 48 mR/HR YES NO 72 mR/HR YES NO
'.45 R/HR RI-8017 FUEL *.3 R/HR *f HANDLING t* Variable EQUIPMENT .04 R/HR Variable YES NO (3) YES NO RI-8018 PERSONNEL ACCESS HATCH 1 .04 R/HR I 1 .04 R/HR I YES NO I j .a6 R/HR / YES NO I 1 1 *1.2 1 I 1 *1.8 1 RI-8019 R/HR R/HR INCORE **
- INSTRUMENT Variable Variable TANK .04 R/HR (4) YES NO (3) YES NO
- Reactor critical *
- Reactor shut down NOTE: NUMBERS IN PARENTHESES REFER TO NOTES ON PAGE 7 OF THIS SUPPLEMENT.
(continued next page)
PROC.MIORKPLAN NO. PROCEDUREM~ORKPLAN TITLE: PAGE: 49 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-15-0 SUPPLEMENT 6 Page 10 of 11 WARNING SETTING ALARM SETTING IS AS - LEFT HIGH IS ALARM AS - LEFT SETPOINT MONITOR SETPOINT AS-LEFT MAXIMUM < MAX INDICATOR MAXIMUM 2 HIGH HIGH HIGH NUMBER/ MINIMUM AS-LEFT NORMAL NORMAL ALARM ALARM ALARM DESCRIPTION SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT SETPOINT
- . 08 *.I2 R/HR R/HR RI-8020 ** **
EQUIPMENT Variable Variable HATCH .04 R/HR (4) YES NO (3) YES NO 2RITS-8001A High Alarm 800 CPM Setpoint N/A N/A N/A N/A (5) YES NO 2RITS-8001B High Alarm 800 CPM Setpoint N/A N/A N/A N/A (5) YES NO NOTE: NUMBERS I N PARENTEESES REFER TO NOTES ON PAGE 7 OF T H I S SUPPLEMENT.
3.2 IF "No" is circled in the above table, THEN perform the following:
Immediately notify the Shift Manager/CRS Document reason for raised background in section 4.0 Initiate corrective actions as required Performed By Operator Date/Time
PROC.MIORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 50 of 50 1305.001 RADIATION MONITORING SYSTEM CHECK AND TEST CHANGE: 014-15-0 SUPPLEMENT 6 Page 11 of 11 4.0 SHIFT MANAGER REVIEW AND ANALYSIS (circle one) 4.1 Are the As-Left Setpoints within the Maximum Normal Setpoints?. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . YES NO 4.2 Do the As-Left High Alarm Setpoints fall within the Maximum High Alarm Setpoints? . . . . . . . . . . . . . . . . . . . . . YES NO 4.3 -
IF answer to 4.1 or 4.2 is "NO",
THEN describe the action taken below 4.4 Have all of the administrative requirements of this test been satisfied (i.e., all initial blocks initialed or N/ACd,all data entered, applicable signature spaces signed, etc.)?. . . YES NO SHIFT MANAGER DATE
JOB PERFORMANCE MEASURE TUOI NUMBER: AIJPM-RO-AOP28 Page 1 of 4 UNIT: 1 REV # : 2 DATE:
TUOI NUMBER: AlJPM-RO-AOP28 SYSTEM: Emergency and Abnormal Operations TASK: Respond to Lo-Lo Instrument Air Pressure.
JTA -
ANOI-RO-AOP-OFFNORM-178 KAVALUE RO: 3.7 SRO: 3.9 KA
REFERENCE:
065 AK3.08 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:
SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):
PLANT SITE: SIMULATOR: X LAB:
POSITION EVALUATED: RO: SRO:
ACTUAL TESTING ENVIRONMENT: SIMULATOR: - PLANT SITE: LAB:
TESTING METHOD: SIMULATE: PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 20 minutes REFERENCE(5): 1203.024, Chg. 010-08-0 EXAMINEE'S NAME: SSN: - -
EVALUATOR'S NAME:
THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
JOB PERFORMANCE MEASURE TUOI NUMBER: AlJPM-RO-AOP28 Page 2 of 4 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough" portion of 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS: Instrument Air pressure dropping due to unisolable leak on IA main line. ICW RB isolation valves inadvertently closed and will not reopen. Plant Shutdown commenced at >I08 per minute per Rapid Plant Shutdown 1203.045. PZR Level 290" and trending up.
TASK STANDARD: Rx Tripped, EEW in service, Seal Injection isolated, and RCP's secured with normal and alternate seal bleedoff flowpaths isolated.
TASK PERFORMANCE AIDS: 1203.024 Section 2.
JOB PERFORMANCE MEASURE TUOI NUMBER: A1 JPM-RO-AOP28 Page 3 of 4 INITIATING CUE :
The SM/CRS directs you to perform 1203.024 Section 2 Lo-Lo Instrument Air Pressure step 3.6 through step 3.6.6.
CRITICAL E W N T S (C): 1, 4, 5, 6, 7, 8
( C1 PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT
- 1. Manually trip Reactor, On C03, depressed the verify all rods Rx Trip pushbutton.
inserted and power (C) dropping. On C13, observed all rod bottom lights have - -
come on. On C03 observed power dropping.
- 2. Manually trip the On C01, depressed the turbine and verify all Turbine Trip throttle and governor pushbutton and valves closed. verified all TVs and GVs closed.
- 3. Check adequate SCM. On ICC display on C19 (or C041, verified that SCM is adequate. - -
(C) 4. Actuate EEW for both On C09, All 4 E m push OTSG' s . buttons pushed on EFIC remote matrix. - -
(C) 5. Isolate Seal Injection On C04, placed HS-1206 by closing CV-1206. in close position. -
(Cl 6. Trip all running On C13 tripped All RCP' s . running RCP' s .
P-32A/P-32B/P-32C/P-32D.
(Cl 7. Isolate Alternate Seal On C13, placed SV-1270 Bleedoff flowpath to thru SV-1273 the Quench Tank. handswitches in closed -
position.
(Ci 8. Isolate Normal Seal On C16, close CV-1274 Bleedoff flowpath. or on C18 close -
CV-1270 thru CV-1273.
END
JOB PEFWORMANCE MEASURE TWO1 NUMBER: AlJPM-RO-AOP28 Page 4 of 4 JPM INITIAL TASK CONDITIONS:
a Instrument Air pressure dropping due to unisolable leak on IA main line.
ICW RB isolation valves inadvertently closed and will not reopen.
Plant Shutdown commenced at >lo% per minute per Rapid Plant Shutdown 1203.045.
PZR Level 290" and trending up.
INITATING CUE :
The SM/CRS directs you to perform 1203.024 Section 2 Lo-Lo Instrument Air Pressure step 3.6 through step 3.6.6.
ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLEAR ONE TITLE LOSS OF INSTRUMENT AIR DOCUMENT NO CHANGE NO 1203.024 010-08-0 WORK PLAN EXP DATE TC M P DATE NIA NIA SET # SAFETY-RELATED IPTE
, BYES DNQ BYES BNO TEMP ALT DYES E N 0 When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Distraction/lnterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First Shiftltast Shift Knowledge Peer Pressure Procedures ChangelOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME FORM TITLE: I FORM NO. I CHANGE NO.
VERIFICATION COVER SHEET I 1000.006A 1 050-00-0
PROC.WORK PLAN NO. PROCEDUREWORK PLAN TITLE:
PAGE: 7 Of 24 1203.024 LOSS OF INSTRUMENT AIR CHANGE: 010-08-0 SECTlON 2 -- LOW-LOW INSTRUMENT AIR PRESSURE (560 PSIG)
DISCUSSION The air pressure in the IA line(s) nearest the leak will be lower than the indicated air beader pressure. For this reason, components nearest the leak will exhibit abnormal indication and abnormal control characteristics first. The longer air pressure rrlndins degraded, the greater the number of malfunctions.
1f IA pressure continues to degrade, power reduction at the maximum rate is specified to minimize plant impact. Close monitoring of air operated systems and components is required to minimize transients resulting from failures. For additional discussion, see Attachment D.
1.0 SYMPTOMS i.1 IA header pressure 560 psig.
2.0 IMYEDIATE ACTION None.
3.0 FOLLOW-UP ACTIONS 3.1 Commence plant shutdown at 210% per minute per Rapid Plant Shutdown (1203.045) while continuing with :his procedure.
3.1.1 -IF instrument air pressure recovers (>60 psig),
THEN stop plant shutdown.
3.2 -
IF IA header pressure drops below 35 psig, 02 any system degrades to the extent that in the judgment of the operator requires reactor trip, THEN GO TO Section 3, "Loss of Instrument Air Pressure (535 PSIG)".
3.3 Place RCP Seal INJ Block (CV-1206) pushbutton in OVRD (OVRD light On)
NOTE Using HPI Block Valves CV-1220 or CV-1285 will minimize nozzle stress cycles because of the normal makeup path.
Pressurizer Makeup Flow Control Valve (CV-1235) will fail as is, when IA pressure drops to -45 psig. I 3.4 -
IF necessary to maintain pressurizer level 5100",
THEN use HPI block valves to provide makeup to RCS, or take manua:
control of CV-1235 as follows:
3.4.1 Align srem and gear holes.
3.4.2 Install lock pin.
3.4.3 Open equalizing valve.
PROC.NORK PLAN NO. PROCEDURENORK PLAN TITLE:
PAGE: 8 of 24 1203.024 LOSS OF INSTRUMENT AIR CHANGE: 010-08-0 SECTION 2 -- LOW-LOW INSTRCMENT AIR PRESSURE (continued) 3.5 IF necessary to maintain pressurizer level <290",
@ ICW is available to RCP seal coolers, THEN perform one or both of the following (3.5.1, 3.5.2) as required:
3.5.1 Isolate seal injection by closing RCP Seal INJ 3lock (CV-1206).
3.5.2 Perform the following:
A. Secure the operating makeup pump.
B. Verify letdown isolated.
C. Perform actions of Loss of Reactor Coolant Makeup (1203.026).
3.6 IF ICW is available to RCP seal coolers,
@ pressurizer level reaches 290",
THEN perform the following:
3.6.: Trip the reactor and perform Reactor Trip (1202.001) in con]unction with this procedure.
3.6.2 Fully actuate ZFW to both SGs.
3.6.3 Close CV-1206.
3.6.4 Trip all running RCPs.
3.6.5 Place the following RCP Seals Bleedoff (Alternate Path to Quench Tank) in CLOSE:
3.6.6 Isolate RCP Seal Bleedoff (Normal) by closing either A or B below:
A. CV-1274, or 3.6.7 Refer to 1202.001 and continue with this procedure.
PROC.MIORK PLAN NO, PROCEDUREMlORKPLAN TITLE:
PAGE: 9 of 24 1203.024 LOSS OF INSTRUMENT AIR CHANGE: 010-08-0 SECTION 2 -- LOW-LOW INSTRUMENT AIR PRESSURE (continued]
3.7 -
IF 2VSF-9 is out of service, THEN direct Unit 2 to perform the following due to IA pressure no longer being sufficient for 2VSF-9 outside air damper operation:
3.7.1 Declare 2VSF-9 inoperable.
3.7.2 Place 2VSF-9 Outside Air Damper (2PCD-86078) in RESIRVE.
3.8 Continue with efforts to rerurn I A pressure to normal as directed by Section 1, "Low lnstrument Air Pressure (575 PSIG)".
Page 1of 5 JOB PERFORMANCE !vlEASURE Unit: 1 Rev # 0 Date:
TUOf NUMBER: AlJPM-RO-CAO1 S y s t e d u t y Area: Chemical Addition System Task: Borate via alternate path bypassing batch controller JA# ANOl-RO-CA-NORM-2 KA Value RO 3.1 SRO 3.3 KA Reference 004 K6.13 Approved For Adminisbation To: RO 5 SRO 5 Task Location: Inside CR: Outside CR: 5 Both:
Suggested Testing Environment And Method (Perform Or Simulate #):
Plant Site: Simulate Simulator#: Lab:
Position Evaluated: RO: SRO:
Actual Testing Environment: Simulator #: Plant Site: Lab Testing Method: Sirnulate: Perform:
Approximate Completion Time In Minutes: 20 Minutes Reference(s): 1305.001, Chg. 017-04-0 Examinee's Name: SSN:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Start Tnne Stop T~me Total Time Signed # Date:
- TQ-202 attachment 9 is complete and on file for performance of this JPM for the current Reactor core configuration.
Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision
TUOI NIJMBER: AlJPM-RO-CAOl THE EXAMTNER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS:
Plant is in process of cooling down for a refueling outage. Boration was in progress to establish refueling boron concentration when batch controller sto!J~edfunctionine.
TASK STANDARD:
Boration of 200 gallons com~letedwith batch controller bvaassed.
TASK PERFORMANCE AIDS:
1103.004 section 9.0
TUOI NUMBER: A1JPM-RO-CAOI INITIATING CUE: The CRS directs you to bypass the batch controller per section 9.0 of 1103.004 and add 200 gallons of boric acid.
This procedure section is complete through step 9.1.7.
CRITICAL ELEMENTS (c):
Ic1 PERFORMANCE CHECKLIST I STANDARD I NlA I SAT I UN 1
............. I . -I.-. I. . ...
~ E ~ y l N ~ R h 2 T s~h:c y U-~atecslitei titc nced for a local operalor, then inlontt trrinee a11 operator is a,rilable.
.. -... --.7 1 1 1. Station an operator at FI-1608 with communications withControlRoom.
Stated the need to station an operator locally at MU Filter Flow Indicator, I I - ..... ........ 1 ............ L...... -+
EXAMINER NOTE When rninee slates thc nccd to close CV-1251. thcn inform r ~ ~ i n \.;rlvc e c is closed.
.- -. ....................... - .... 7.
.. .. l
/ / 2. Close Condensate to Batch Controller CV-1251. I Called Control Room and requested / 1 / I closure of CV- 1251 POSITIVE CUE:
CV-1251 closed.
I I I I I 1 3. Verify valves at BAAT closed. 1 At BAAT, verified the following valves closed: - - -
POSITIVE CUE: Boric Acid to SFP CA-78 Valves are closed.
........... .-... .-...1 ....
. Boric Acid to BWST CA-76 FI-1608 Bypass CA-1608-3.
-.. --.- I I EXAMliLER YOTE. Step 0.2.4 is YIA.
- 4. Unlock and close Boric Acid to Batch Controller, CA- Unlocked and closed Boric Acid to
- 73. Batch Controller, CA-73. Mentioned need to make Cat-E log entry (not - -
POSITIVE CUE: required for full credit).
Unlocked and closed CA-73.
- 5. Verified CA-72 closed and CA-71 open. In " B MU pump room, verified Boric Acid Line Flush to ABD POSITIVE CUE: Header CA-72 closed and Boric Acid - -
CA-72 closed, CA-71 open. to Makeup Filters CA-71 open.
- 6. Venfy valves at BAAT open. At BAAT, verified the following valves open:
POSITIVE CUE: Boric Acid to MU Filters Root - - -
Valves are closed. Isol CA-69 FI-1608 Inlet CA-1608-1 FI-1608 Outlet CA-1608-2
Page 4 of 5 TUOI NUMBER: AlJPM-RO-CAOl POSITIVE CUE:
P-39A red light ON.
POSITIVE CUE:
Trainee calculated 200 gallons.
~ x ~ ~ M I UVOTE. E K i4fir.r trainre stops punip. then inlonn vrinee that i h i ~ i r ere-aliyunent is u a r r e s a q and ,411. B llis bren opd:itud
. I . , . . . . . ..
- 9. Stop rnnning boric acid pump. At C101, stopped boric acid pump P-C POSITIVE CUE:
39A. ---
P-39A stopped.
TUOI NUMBER: AIJPM-RO-CAOl INITIAL CONDITIONS:
Plant is in process of cooling down for a refueling outage.
Boration was in progress to establish refueling boron concentration when batch controller stopped functioning.
INITIATING CUE:
The CRS directs you to bypass the batch controller per section 9 0 of 1103.004 and add 200 gallons of boric acid.
This procedure section is complete through step 9.1.7.
Distractionflnterruption Questioning Affitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShlWLast Shift Peer Pressure Procedures ChangelOff Norma1 Job Briefing PhysDcal Environment I VERIFICATION COVER SHEET
PROC.IWORK PLAN NO. PROCEDURUWORKPLAN TITLE:
PAGE: 22 of 90 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 017-05-0 9.0 Boration - Alternate Method From BAAT, Bypassing Batch Controller:
9.1 Initial Conditions 9.1.1 Xakeup and purification system in opcrotion per Makeup &
Purification System Operation (1104.002) "System Startup" section.
9.1.2 Chemical addition system aligned per Chemical Addition (1104.003), Attachment F.
9.1.3 -
IF manual bleed is :o be initiated, THEN verify the following:
A. Vacuum degasifier either bypassed or in-service per Vacuum Degasifier Operations (1104.016).
B. Clean liquid waste system in operation per Clean Waste System Operation (ii04.020), "Initial Startup" seccion.
9.1.1 Sample RCS and boric acid source to determine boron concentration as needed.
NOTE Simultaneous boric acid addition to the Makeup System using both batch controller and bypassing batch controller flow paths is permitted during RCS cooldown in Modes 3 and 4.
9.1.5 Unless during plant cooldown, verify no other transfer of boric acid from BAAT in progress.
NOTE When using the BORON program, any operating conditions may be input.
Attachment C and the BORON program automatically add 167,000 lb. to the reactor coolant mass when RCS temperature is < 250.O0F, to account for the decay heat system.
9.1.6 Perform the following calculations:
A. Use Attachment A.3 OR Plant Monitoring System BORON program to determine volume needed.
B. Xecord volume of batch to be added on Attachment 9, RCS Liquid Addition Data Sheet.
C. Obtain an RO/SRO independent review of calculation and record on Attachment B.
D. I_r needed, THEN complete "BAAT Inventory Planning Sheet",
Attachment A.lO.
PROC.IWORK PLAN NO. PROCEDURUWORK PLAN TITLE:
PAGE: 23 of 90 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 017-054 9.1.7 Ensure adequate storage availability exists for any waste to be generated, if applicable.
Compare volume of feed calculated in above step vs.
available T-12s.
IF T-12s cannot receive required volume, THEN transfer applicable 7-12s to Unit 2 per Clean Waste System Operation (1104.020).
NOTE The following alignment retains the ability to borate to cold shutdown. For boric acid additions, other than boration to cold shutdown, an operator is required at MU Filter Flow IND (FI-1608) for flow monitoring. I 9.2 Zstablish addition lineup as follows:
9.2.1 Verify the following valves in the '3' MU pump room:
Boric Acid Line Flush to ABD Header (CA-72) closed.
Boric Acid to Makeup Filters Isol (CA-71) open.
9.2.2 Close Condensate to Batch Controller (CV-i251).
9.2.3 Verify the following valves at the BAAT closed:
. Boric Acid to SF Pool (CA-78) e Boric Acid to BWST (CA-76)
FI-1608 Bypass (CA-1608-3)
I NOTE Aliunment for simultaneous addition throuuh batch controller and batch I I coniroiler bypass should not be used except during RCS cooldown in Mode 3 or Mode 4.
9.2.4 -IF this lineup is for simultaneous addition through batch controller AND batch controller bypass during RCS cooldown, THSN verify Boric Acid to Batch Controller (CA-73) open.
9.2.5 -IF lineup is for any other activity, THEN unlock and close CA-73.
A. Make appropriate entry in Category E/Locked Component Log (E-DOC 1015.001H).
9.2.6 Verify the following valves open at the BAAT:
- Boric Acid to MU Filters Root Isel (CA-69)
FI-1608 Inlet (CA-1608-1)
FI-1608 Outlet (CA-1608-2)
PROC.MIORK PLAN NO. PROCEOURElWORK PLAN TITLE:
PAGE: 24 of 90 1103.004 SOLUBLE POISON CONCENTRATION CONTROL CHANGE: 017-05-0 9.2.7 Station an operator at FI-1608 with communications with Control Room.
I CAUTION Do NOT run a boric acid pump dead-headed for more than 30 seconds. 1 NOTE Local operation of boric acid pumps must be performed by a licensed operator, or an RO trainee in the presence of a licensed operator.
9.3 Operate Boric Acid Pump(s) (2-39A or P-39B or both) locally from Boric Acid Panel ClOI OR remotely from C04 to add desired volume recorded on Attachment B.
9.3.1 Calculate volume addition by multiplying MU Filter Flow IND (FI-1608) flow rate by time in minutes BA pump(s) are run.
9.3.2 Verify RCS concen~rationat each 30 ppmB interval by chemistry sampie.
9.4 WHEN desired addition is complete AND it is desired to realign the Batch Controller, THEN perform the following:
9.4.1 Stop the running boric acid pump(s).
9.4.2 Close CA-71.
9.4.3 Close CA-69.
9.4.4 -
IF CA-73 was closed, THEN perform the following:
A. Cpen CA-73.
- 3. Lock CA-73.
C. Complete required encry on Category E/Locked Component Log (E-DOC 10i5.001H).
D. lerform required Independent Verification that CA-73 is open AND locked.
E. Complete rcquired entry on Category E/Locked Component Log (a-DOC 1015.001H).
9.5 Update Attachment 3.
TUOI NUMBER: Page 1 of 5 A I JPM-RO-EFWO 1 JOB PERFORMANCE MEASURE Unit: 1 Rev # 11 Date: 01/12/2004 TUOl NUMBER: AIJPM-RO- EFWO 1 System'Duty Area: Emergency Feedwater and EFIC Task: Reset the Steam Driven Emergency Feedwater Pump after an overspeed trip JA# AN0 1-RO-EFW-NORM- 13 KA Value RO 3.4 SRO 3.8 KA Reference 061 A2.04 Approved For Administration To: RO [XI SRO [XI Task Location: Inside CR. C] Outside CR: [XI Both: C]
Suggested Testing Environment And Method (Perfom Or Simulate): Simulate Plant Site: Perform Simulator: Lab:
Position Evaluated: RO: X SRO: X Actual Testing Environment: Simulator: Plant Site: Lab Testing Method: Simnlate: X Perform:
Approximate Completion Time In Minutes: 15 Minutes Reference(S): 1106.006 Exhibit A and Exhibit B, change 064-07-0.
Examinee's Name: SSN:
Evaluator's Name:
The Examinee's performance was evaluated against the standards contained in this JPM and is determined to be:
Satisfactory: Unsatisfactory:
Performance Checklist Comments:
Stan Time Stop T i e Total Time Signed Date:
Signature indicates this JPM has been compared to its applicable procedure by a qualified individual (not the examinee) and is current with that revision.
TUOI NUMBER:
AlJPM-RO-EFWOI THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrough portion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS:
P7A Emergency Feedwater Pump has tripped on overspeed during an EFIC actuation.
TASK STANDARD:
P7A turbine has been reset per 1106.006 Exhibit A.
TASK PERFORMANCE AIDS:
OP 1106.006 Exhibit A and B SIMULATOR SETUP:
N/A
TUOI NUMBER:
AlJPM-RO-EFWO1 INITIATING CUE: The SMICRS directs you to reset P7A overspeed trip per 1106.006, Exhibit A CRITICAL ELEMENTS (c): 2.3, and 8 C PERFORMANCE CHECKLIST STANDARD N/A SAT UN SAT EXAMINER'S NOTE: Simulate communications with the Control Room.
- 1. Verify the following valves are closed. If ERN Called control room to verify SV-initiate signal is present, manual control is required. 2613, SV-2663, CV-2613, CV-EFW Pump Turbine K3 Steam Admission 2663 are closed.
Valves (CV-2613 and CV-2663)
EFW Pump Turbine K3 Steam Admission Valve Bypasses (SV-2613 and SV-2663)
POSITIVE CUE:
SV-2613, SV-2663, CV-2613. CV-2663 have valve stems full out with handwheel's full CW.
- 2. Tum EFW Turbine K3 Trip-Throttle Valve (CV- Trip1Throttle valve (CV-6601A) 6601A) handwheel clockwise. Observe rotation of handwheel turned clockwise until screw raises sliding nut and latch lever to where it sliding nut rises and latch lever will engage the trip hook. engages the trip hook.
POSITIVE CUE:
Trip/ Throttle valve (CV5601A) sliding nut raised and latch lever has engaged the trip hook.
C 3. Pull spring-loaded connecting rod against spring Connecting rod pulled against force to move head lever away from tappet and spring force to move head lever tappet nut. away from tappet and tappet nut.
POSITIVE CUE:
Head lever moved away from tappet and tappet nut.
I
- 4. Lift and release tappet assembly Tappet assembly lifted and released.
POSITIVE CUE:
Tappet assembly lifted and released.
- 5. Verify tappet nut in trip reset position Verified tappet nut in trip reset position.
POSITIVE CUE:
Tappet nut in trip reset position
TUOl NUMBER:
AIJPM-RO-EFWO1 C PERFORMANCE CHECKLIST STANDARD NIA SAT UN
. . . . . .- . ..-....................... SAT 1 1 6 Obsewe tappet returns to reset position Observed tappet returns to reset position. - - -
I ! POSITIVE CUE:
Tappet is in reset position.
- 7. Verify the following: Verified tappet nut in trip reset Tappet nut in trip reset position and properly position and properly aligned.
. aligned. Verified spring tension holds Spring tension holds connecting rod in position. connecting rod in position.
POSITIVE CUE:
Tappet nut in trip reset position and properly aligned Spring tension is holding connecting rod in position.
C 6. Slowly turn CV-66OlA handwheel CV-6601A fully opened.
counterclockwise until valve is fully open.
POSITIVE CUE:
CV-6601A has valve stem full out with handwheel in the full CW position.
- 9. Close valve (CV-6601A) 314 turn to prevent binding CV-6601A closed 314 turn.
on heatup. - - -
- 10. Verify P-7A TURBINE TRIP (K12-85) clear. Call Control Room and verified POSITIVE CUE:
that P-7A TURBINE TRlP (K12-
- 55) is clear.
P-7A TURBINE TRlP (K12-85) clear
- 11. Notify Control Room that P-7A is ready for restart. Control Room notified that P-7A is ready for restart. - - -
POSITIVE CUE:
Control Room notified that P-7A is ready for restart.
I ........................ 1 1........__L 1 EXAMINERS CUE: This concludes the JPM.
-- -- .... .. ..... --- . . . ................ I
TUOI NUMBER:
AIJPM-RO-EFWO1 EXAMINEE'S COPY INITIAL CONDITIONS:
P7A Emergency Feedwater Pump has tripped on overspeed during an EFlC actuation.
INITIATING CUE:
The SMICRS directs you to reset P7A overspeed trip per 1106.006, Exhibit A.
When you see these mme Pressure Effective Communication Distractionnnterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShiftlLast ShiR Peer Pressure Procedures ChangelOff Normal Job Briefing
I PROC.IWORK PLAN NO. PROCEDUREMlORK PLAN TITLE: PAGE: 60 of 193 1106.006 EMERGENCY FEEDWATER PUMP OPERATION CHANGE: 064-074 04/30/05 EXHIBIT A Page 1 of 2 EMERGENCY FEEDWATER PUMP ?-7A OVERSPEED TRIP RESET
/ 1.0 Verify the following valves are closed:
I i 1.1 -
IF EFW initiate signal THEN manual control is
. EFW Pump Turbine K3 is present, required:
Steam Admission Valve (CV-26131 2FW Pump Turbine K3 Steam Admission Valve (CV-26631 E m Pump Turbine K3 Steam Advission Valve Bypass (SV-26131 8 EFW ?ump Turbine K3 Steam Admission Valve Bypass (SV-26631 1 2.0 Turn EFW Turbine K3 Trip/Throttle Valve (CV-6601A) handwheel clockwise.
I I 2.1 Observe rotation of screw raises sliding nut and latch lever to where it wil; engage the trip hook.
3.0 Manually reset mechanical trip linkage as follows:
I I 3.1 3.2 Pull spring-loaded connectinq rod against spring force to move head lever away from tappet and tappet nut.
Lift and release tappet assembly.
I I 3.2.1 Observe tappet returns to reset position.
I CAUTION
-If necessary to manually push tappet down into position, force must be applied straight downward to prevent bending aluminum tappet.
3.2.2 IF tappet spring force did not move tappet into proper position, THEN manually press tappet straight downward into position.
3.2.3 IF it was necessary to manually reposition tappet, THEN notify CXS, AND upon completion verify Condition Report initiated.
PROC.MIORK PLAN NO. PROCEOURE~ORKPLAN TITLE: PAGE: 61 of 193 1106.006 EMERGENCY FEEDWATER PUMP OPERATION CHANGE: 064-07-0 1106.006 04/30/05 EXHIBIT A Page 2 of 2 EMERGENCY FEEDWATER PUMP P-7A OVERSPEED TRIP RZSET NOTE Flat side of tappet nut must be a l i g n e m the flat of the head lever (parallei to shaft). Otherwise latch lever and trip hook can disengage when CV-6601A is opened.
3.3 Verify the following:
A. Tappet nut in trip reset position AND properly aligned.
B. Spring tension holds connecting rod in position.
NOTE Steam pressure trapped between Steam Admission Valves and CV-6601A will I
I be admitted to turbine when CV-6601A is opened and may result in turbine rotation.
CV-6601A must indicate open to clear overspeed trip alarm.
3.4 Slowly turn CV-660lA handwheel counterclockwise until valve is fully open.
3.4.1 Close valve 3/4 turn to prevent binding on heatup.
3.4.2 Verify 2-7A TURBINE TRIP (K12-B5) clear.
4.0 Notify Control Room that P-7A is ready for restart.
PROC.NVORK PLAN N
O. PROCEDURE
NVORK PLAN TITLE: PAGE: 62 of 193 1106.006 EMERGENCY FEEDWATER PUMP OPERATION CHANGE: 064-07-0 1106.006 EXHIBIT B EMERGENCY FEEDWATER PUMP P-7A OVERSPEED TRIP MECHANISM
JOB PERFORMANCE MEASURE TUOI: AIJPM-RO-ED030 Page 1 of 5 UNIT: 1 R E V # L DATE:
TUOI NUMBER: A1lPM-RO-ED030 SYSTEMDUTY AREA: BATTERY AND 125V DC DISTRIBUTION TASK: PLACE BATTERY CHARGER D-03B IN SERVICE
.lTA#: ANO1-AO-125DC-NORM-I2 KA VALUE RO: 3.9 SRO: 3.4 KA
REFERENCE:
2.1.30 APPROVED FOR ADMINISTRATION TO: RO: X SRO. X TASK LOCATION: INSIDE CR: OUTSIDECR: X BOTK:
SUGGESTED TESTJNG ENVIRONMENT AND METHOD (T'ERFORM OR SIMULATE):
PLANTSITE: X SIMULATOR: LAB:
POSITION EVALUATED: RO: X SRO: X ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANTSITE: X LAB:
TESTING METHOD: SIMULATE: X PERFORM:
APPROXIMATE COMPLETION TIME IN MINUTES: 20 MINUTES REFERENCE(S): 1107.004, Che. 012-13-0 EXAMINEE'S NAME: SSN --..---
EVALUATOR'S NAME THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:
SATISFACTORY: UNSATISFACTORY:
PERFORMANCE CHECKLIST COMMENTS:
Start Time Stop Time Total Time SIGNED DATE:
SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.
JOB PERFORMANCE MEASURE TUOI: AIJPM-RO-ED030 Page 2 of 5 THE EXAMINER SHALL REVIEW TEE FOLLOWING WITH THE EXAMINEE:
The examiner shall review the "Briefing Checklist - System Walkthrongh" partion of OP 1064.023 Attachment 6 with the examinee.
JPM INITIAL TASK CONDITIONS:
Battcrv Charger D-03A is in service on Battew DO1 TASK STANDARD: IAW 1107.004, Att. B, examinee places charzer D-03B in service, removes D-03A from service, and performs actions for D-03A DC output voltage drifting to zero.
THIS IS AN ALTERNATE SUCCESS PATH JPM.
TASK PERFORMANCE AIDS: 1107.0004 Attachment B
JOB PERFORMANCE MEASURE TUOI: AlJPM-RO-ED030 Page 3 of 5 INITIATING CUE:
The Shift Manager requests you to place Battery Charger 0-038 in service on Bus DO1 and remove Battery Charger D-03A from service.
CRITICAL ELEMENTS (C) 5.6. 8, 9. 12, 15, 17 (C) I Pf;KI;ORZIA?ICL: CHECKLIST 1 STASDARD 1 I
NJA II SAT /USSAl'
- 1. Verify breakers open for charger On front of charger 0-038, verified 0-038. the AC lnput and DC Output breakers AC lnput breaker open (OFF).
DC Output breaker
- 2. Verify AC feeder breaker to charger Verified breaker B-5733 closed (ON) 0-038 closed (8-5733).
- 3. Verify charger D-03B supply to bus Inside panel D01, verified breaker breaker closed (DO1-42). DO1-42 closed (ON). - -
- 4. Verify Manual Disconnect for At D13, verified manual disconnect - -
battery 0-07 closed (D-13). for battery DO7 closed (ON).
- 5. Close D-038 AC Input breaker. On front of charger 0-038, closed the AC Input breaker (ON). 1-1-1 1 1 6. Close 0-038 DC Output breaker. On front of charger 0-038, closed the DC Output breaker (ON). 1 - 1
- 7. Wait -1 minute for automatic load Waited -1 minute, observed rising sharing to occur. amps on D-03B and falling amps on D-03A.
CUE: Amps are rising on D-038 output ammeter and amps are falling on D-03A output ammeter.
I I (c) 9. Open D-03A AC lnput breaker. On front of charger D-03A, opened the AC Input breaker (OFF).
1-1-1
JOB PERFORMANCE MEASURE TUOI: AlJPM-RO-ED030 Page 4 o f 5 (c) ! PERFORMANCECHECKLIST STANDARD I N/A I SAT 1 UNSAT
- 10. Check Charger D-03B picks up At charger D-03B checked ammeter load. deflected to a nominal value, and at DO1 checked bus voltage maintained CUE:
. D-036 DC Out -100 amps AC In -30 amps at -130 volts.
DO1 bus voltage 130V
- 11. Reset local alarm panel for Charger At charger D-036, pressed "R" button - - -
D-038. on RIS panel.
- 12. Place 0-038 alarm to control room toggle switch ON.
At charger 0-038, placed control room alarm switch to ON (up). l-lp1-!
I I 13. Place D-03A alarm to control room toggle switch OFF.
At charger D-03A, placed control room alarm switch to OFF (down). I-14-l
- 14. Check annunciator DO1 CHARGER Called control room and requested TROUBLE (K01-E7) clears. check for clear annunciator K01-E7.
I I I I I I ALTERNATE PATH CUE: Inform examinee that D-03A DC Output Voltage drifted to zero, also inform examinee that one minute has passed since D-03A was de-energized.
I I I I I I 15. Close D-03A AC lnput breaker. On front of charger D-03A, closed the AC Input breaker (ON).
- 16. Check D-03A DC output voltage On charger D-03A, obsewed DC and AC input voltage. output voltage and AC input voltage meters.
CUE:
DC Output Voltage -90V Examinee stated that he would AC lnput Voltage -480V contact electrical maintenance for support.
I I(q 17. Open D-03A AC lnput breaker. On front of charger D-03A, opened the AC Input breaker (OFF).
1-1/-1
- 18. Submit condition report and WR. Examinee stated that he would submit a condition report and Work Request or Work Order on D-03A.
I I I I I JPM Complete
JOB PERFORMANCE MEASURE Page 5 of 5 EXAMINEE'S COPY JPM INITIAL TASK CONDITIONS:
Battery Charger D-03A is in service on Bus DO1 INITIATING CUE:
The Shift Manager requests you to place Battery Charger D-03B in service on Bus DO1 and remove Battery Charger D-03A from service per 1107.004, Battery and 125V DC Distribution, Attachment B.
ENTERGY OPERATIONS INCORPORATED ARKANSAS NUCLEAR ONE TITLE BATTERY AND 125V DC DISTRIBUTION DOCUMENT NO CHANGE NO 1107.004 012-130 WORK PLAN EXP DATE TC EXP DATE NIA NIA SET # SAFETY-RELATED IPTE NYES ONO @YES UNO TEMP ALT nYES E N 0 When you see these TRAPS Get these TOOLS Time Pressure Effective Communication Distractionllnterruption Questioning Attitude Multiple Tasks Placekeeping Over Confidence Self Check Vague or Interpretive Guidance Peer Check First ShiWLast Shift Knowledge Peer Pressure Procedures ChangelOff Normal Job Briefing Physical Environment Coaching Mental Stress (Home or Work) Turnover VERIFIED BY DATE TIME FORM TITLE: FORM NO. CHANGE NO.
VERIFICATION COVER SHEET 1000.006A 050-00-0
PROC.MI0RK PLAN NO. PROCEOURENVORK PLAN TITLE: PAGE: 24 of97 1107.004 BATTERY AND 125V DC DISTRIBUTION CHANGE: 012-13-0 ATTACHMENT B Page 1 of 3 PLACING BATTERY CHARGER D-03B INTO SERVICE NOTE Section 1 contains instructions for placing D-03B into service with D-03A to be removed from service.
Section 2 contains instructions for placing D-03B into service with D-03A out of service.
1.0 To place Battery Charger for DO1 (D-03B) into service and remove charger D-03A from service, perform the following:
1.1 Verify the following breakers open for charger D-038:
A. D-03B AC Input Breaker on charger cabinet front.
B. D-038 DC Output Breaker on charger cabinet front.
1.2 Verify the following breakers closed for charger D-03B:
A. Battery Charger D-038 (B-5733)
B. Supply from Battery Charger D-038 (D01-42). Breaker inside cubicle, no external handle.
1.3 Verify Battery D-07 Manual Disconnect (D-13) closed 1.4 Close D-03B AC Input Breaker on cabinet front CAUTION Cycling Battery Charger Output Breaker could cause inservice inverters associated with this Battery Charger to swap to alternate source and blow fuses.
1.5 Close D-03B DC Output Breaker on cabinet front.
NOTE Automatic load sharing should equalize the charger load within -1 minute.
However it is not necessary to wait if load does not equalize.
1.6 Wait -1 minute to check for automatic load sharing (rising amps on D-03B, falling amps on D-03A, and then stabilizes).
1.6.1 -
IF load sharing does NOT occur, THEN check D-03B DC output voltage -130 volts AND continue.
PROC.MIORK PLAN NO. PROCEDURE~ORKPLAN TITLE: PAOE: 25 of 97 1107.004 BATTERY AND 12% DC DISTRIBUTION CHANGE: 012-130 ATTACHMENT B Page 2 of 3 NOTE Opening the DC Output Breaker for D-03A may cause its DC output voltage to drift to zero and Local Alarm Panel lights to fade.
(CR-ANO-2-2003-0423).
Open D-03A OC Output Breaker on cabinet front Open D-03A AC Input Breaker on cabinet front.
Check charger D-03B picks up load to maintain proper DC bus voltage:
1.9.1 Charger ammeter deflects to some nominal value 1.9.2 Bus DO1 voltage is maintained at -130 volts.
Reset local alarm panel for charger D-03B.
Place D-03B alarm to control room toggle switch ON Place D-03A alarm to control room toggle switch OFF.
Check annunciator DO1 CHARGER TROUBLE (K01-E71 clears IF D-03A DC output voltage drifted to zero when its DC output breaker was opened, THEN perform the following to prove D-03A operability:
1.14.1 Ensure -1 minute has passed after de-energizing D-03A 1.14.2 Close D-03A AC Input Breaker on cabinet front 1.14.3 Check 0-03A DC output voltage - 130 VDC.
1.14.4 Check D-03A AC input voltage normal - 480 VAC 1.14.5 -
IF D-03A DC output voltage does NOT return to normal, THEN contact electrical maintenance for support.
1.14.6 Open D-03A AC Input Breaker on cabinet front 1.14.7 Perform the following even if D-03A is operable:
. Submit Condition Report
PROC.MIORK PLAN NO. PROCEDUREWORK PLAN TITLE: PAGE: 26 of 97 1107.004 BATTERY AND 125V DC DISTRIBUTION CHANGE: 012-13-0 ATTACHMENT B Page 3 of 3 2.0 To place Battery Charger for DO1 (D-03B)into service with charger D-03A out of service, perform the following:
2.1 Verify the following breakers open for charger D-03B:
A. D-038 AC Input Breaker on charger cabinet front.
B. D-03B DC Output Breaker on charger cabinet front.
2.2 Verify the following breakers closed for charger D-03B:
A. Battery Charger D-038 (8-5733)
B. Supply from Battery Charger 0-038 (D01-42). Breaker inside cubicle, no external handle.
2.3 Verify Battery D-07 Manual Disconnect (0-13) closed.
2.4 Close 0-038 AC Input Breaker on cabinet front 2.5 Close D-03B DC Output Breaker on cabinet front.
2.6 Check charger D-03B picks up load to maintain proper DC bus voltage:
2.6.1 Charger ammeter deflects to some nominal value 2.6.2 Bus DO1 voltage is maintained at -130 volts.
2.7 Reset local alarm panel for charger D-03B.
2.8 Place D-03B alarm to control room toggle switch ON 2.9 Check annunciator DO1 CHARGER TROUBLE (K01-E7) clears.
ES-301 Transient and Event Checklist Form ES-301-5 I. Circle the applicant level and enter the operating test number and Form ES-D-I event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the "at-the-controls (ATC)" and "balance-of-plant (BOP)" positions; Instant SROs must do one scenario, including at least two instrument or component (IIC) malfunctions and one major transient, in the ATC position.
- 2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*)Reactivity and normal evolutions may he replaced with additional instrument or component malfunctions on a I-for-l basis.
Author:
NRC Reviewer:
ES-301, Page 26 of 27
ES-301 Competencies Checklist Form ES-301 Facility: ANO-1 Date of Examination: 9/12/2005 Operating Test No.: 2005-1 APPLICANTS RO (ATC) / RO (BOP) 1 SRO-U Competencies SCENARIO SCENARIO SCENARIO Interpret 1 Diagnose Events and Conditions (1) Includes Technical Specification compliance for an RO.
(2) Optional for an SRO-U.
(3) Only applicable to SROs.
Instructions:
Circle the applicant3 license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
ES-301, Page 27 of 27
ES-301 Competencies Checklist Form ES-301-6 Facility: ANO-1 Date of Examination: 9/12/2005 Operating Test No.: 2005-1 APPLICANTS SRO-I SRO-I (ATC)
Competencies SCENARIO SCENARIO 1 2 3 4 1 2 3 4 3,5,6,7 1,2,3,6,7 2,4,5,6,7,8 2,4,5,6 2,3,6,7 Interpret IDiagnose Events and Conditions 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 1,2,4,5,6,7 Comply With and 6,7,8,9 6,7,8,9 6,7,8,9 6.7,s Use Procedures (1)
NIA NIA NIA NIA 1.2,4,5,6,7 Operate Control Boards (2) 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5 1,2,3,4,5
- - 1,2,3,4,5, Communicate and 6,7,8,9 6,7,8,9 673 ,6,7,8 6,7 (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.
ES-301, Page 27 of 27
A ~ ~ e n dDi x Scenario 1 Form FS-D-1 pleted. Condensate s in "MANUAL".
maintenance to main Feedwater pump and after Heater Drain Pumps in service.
3 TR565 I (CBOR) RCS That slowly fails low Ramp=4 Min.
4 N/A N (CBOR) Place the ICS in AUTO.
5 RX604 C (CBOT) False increasing pulser signal to EHC causes 30%/min. Turbine Generator to raise load.
6 ED191 C (CBOT) Loss of non vital bus 83 7 ED183 M (All) Random electrical grid upsets result in loss of offsite power. Reactor trip. Degraded Power.
8 C (CBOT) EDG #2 service water valve (CV3807) breaker trips IRF ~ ~ 3 8 0 7 during opening causing minimal flow to the EDG for IRF 86231 cooling.
9 DI-A-MSLI-lAFalse C (CBOR) All MSLl pushbuttons on the EFlC Remote Switch DI-A-MSLI-18 False Matrix fail to manually actuate the MSLl function DI-A-MSLI-ZA False requiring alternative effort for performing function.
Dl-A-MSLI-28 False Dl-8-MSLI-1A False Dl-8-MSLI-1B False Dl-8-MSL12A False Dl-8-MSLI-28 False
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor J
ADDendix D Scenario 1 Form ES-D-1 Scenario # Obiectives I
- 1) Evaluate individual response to input signal failures to the lntegrated Control System
- 2) Evaluate individual response to electrical system abnormal conditions
- 3) Evaluate individual response to a loss of offsite electrical power
- 4) Evaluate individual ability to start and control components of the feed and condensate system
- 5) Evaluate individual ability to perform a power escalation in accordance with plant procedures 6 ) Evaluate individual ability to recognize abnormal conditions associated with automatically actuated systems and components
- 7) Evaluate individual response to failure of actuation function associated with the Main Steam Line Isolation portion of EFlC SCENARIO # NARRATIVE I
The scenario begins with a power escalation to 100% in progress following maintenance to the "A" Main Feedwater pump. Power has been stabilized at -70% to place the heater drain pumps in service to provide sufficient feedwater pump suction pressure to continue the power rise to 100%. The crew will place the second heater drain pump in service and begin the power escalation.
As power is raised toward -80% power, an RCS hot leg temperature transmitter, that is providing input to the lntegrated Control System, fails low. This failure, being a slow failure, and therefore the Smart Automatic Signal Selector system will not select the redundant instrument, causes a plant transient that will include control rods to withdraw and feedwater flow to be lowered. The crew is expected to intervene and stop the transient by placing the ICS in "Manual" mode and correct the affected plant parameters to stabilize the plant. Once stable, the crew will select the redundant (good) instrument to provide input to the ICS and perform the normal operation of placing the ICS in "Automatic" mode.
When the ICS is placed in "AUTO" following the temperature transmitter failure, the Turbine will begin rising without a commanded signal. The crew should recognize the rising turbine load and lowering of the turbine header pressure and place the turbine in a manual mode, either "OPER AUTO" or "Turbine Manual". Contacts to support organizations should begin to troubleshoot the turbine malfunction. The Turbine will remain in a manual mode at this time.
An internal breaker fault in the feeder breaker to the non-vital B3 bus will cause the breaker to trip, causing a loss of the non-vital 83 bus. The crew is expected to respond to the loss of B3 using Annunciator Corrective Actions and Abnormal Operating Procedure for Loss of Loadcenter. The crew will start redundant equipment as directed by the operating procedures and stabilize the plant.
eegendlx D Scenario 1 Form FS-D-1 SCENARIO #INARRATIVE (continued)
Due to random electrical grid upsets in the system, a loss of offsite power will occur. The Reactor will trip automatically and the crew will begin addressing the Reactor Trip and degraded power situation. Once the Reactor Trip immediate actions have been completed, the crew will transition to the Degraded Power procedure for guidance.
While verifying the proper operation of actuated components due to the degraded power, the discovery of the service water valve to the #2 EDG failure will require the crew to take action to restore service water to the EDG or stop the EDG to protect it from damage due to overheating.
During performance of actions required by the Degraded Power procedure, the crew will be prompted to actuate MSLl on both OTSGs to establish a "vital island" concept for the heat removal from the primary to the secondary. When the operator attempts to actuate the function from the normally utilized remote switch matrix, the matrix buttons fail to execute the command. The crew must take contingency action to establish the MSLl function. This may be accomplished by manual positioning of the affected components or actuation of the function from the EFIC cabinets in the back of the control room.
The scenario will be terminated when the plant is at a point where the crew is awaiting the return of offsite power or at the discretion of the lead evaluator.
hendix D Scenario 1 Form ES-D-1 Simulator Instructions for Scenario 1 ED183 8 T=67 Actuate EDG #2 service water valve (CV3807)
Trigger 1 breaker trips during opening causing IRF ~ ~ 3 8 0 7 .05 minimal flow to the EDG for cooling.
IRF 86231 OFF 9 Pre-loaded DI-A-MSLI-IA False All MSLl pushbuttons on the EFlC hi^ event Dl-A-MSLl-1B False Remote Switch Matrix fail to manually will occur DI-A-MSL1-2A False actuate the MSLI function requiring when the DI-A-MSLIZB False alternative effort for performing function.
crew Dl-8-MSLI-?A False Dl-8-MSLI-18 False step to actuate Dl-8-MSLI-ZA False MSLl 01-0-MSLI-20 False
Appendix D Required Operator Actions Form ES-D-2 IT=O I CRS I Direct the crew to place the " B Heater Drain Pump in service per 1106.016, Condensate, Feedwater, and Steam System Operation.
I CBOT I At panel CIZ. Start P8B.
CBOT Monitor Heater Drain Pump discharge flow on the plant computer.
CBOT Dispatch the Auxiliary Operator to gradually open the manual discharge valve for P8B, (CS-59B), approximately 5 turns.
IA NOTE: To open CS59B; IRF CS59B .35 60 CBOT Using the controller on C12 for CV2810, slowly throttle closed the associated Recirc Control Valve. Monitor drain tank level, P8B discharge flow, and main feedwater pump suction pressure, while slowly lowering T40B level.
CREW When discharge flow is approximately 0.5 X lo6 lblhr, verify K06-A8 (P8AIP8B FLOW LO) clears.
CBOT WHEN T-40 level -1 1I", THEN place Recirc Control Valve in AUTO.
I CBOT I Verify Recirc Control Valve maintains Heater Drain Tank level -1 11" (-49%).
CBOT Coordinate with the Auxiliary Operator to complete the alignment per the procedure.
I CBOT 1 Return idle Condensate Pump. P-2, handswitch to normal-after-stop I CBOT I Close Low Level Condenser Sprays (CV-2901 and CV-2868) on C02 I I Event Termination:
P8B in service with recirc valve in AUTO Page 5 of 13
Appendix D Required Operator Actions Form ES-D-2 applicable procedures, instructions, ODMls, etc.
NOTE: The normal maneuvering rate for this situation would be 30°h/Hr.
however due to the small failed fuel the unit is experiencing, Reactor Engineering has recommended a rate of 15%/Hr. to 90% power, and 5%/Hr. to 100% in accordance with the ODMl established for this condition.
(This begins the power escalation to approximately 90% power.)
Appendix D Required Operator Actions Form ES-D-2 OpTest No: 2005-1 Scenario No: 1 Event No: 3 Event
Description:
RCS Tm slowly fails low Time - Applicant's -
Actions or Behavior Cued by CBOR Acknowledge and report annunciator alarm K07-B4, SASS Mismatch, is in Evaluator alarm.
CBOR Identify the SASS enable light for the loop "A" Thot instrument on C03 has gone out.
1 CBOR I Identify a plant transient is in progress I I CRS I Direct the CBOR to place ICS in "MANUAL" (At a minimum, the "A" and "B"feedwater loop demands and the Reactor Demand HandIAuto stations should be placed in "MANUAL")
CBOR Place the "A"and " B feedwater loop demands and the Reactor Demand CT handlauto stations in "Manuai" and verify the transient stops. IF the control rods continue to move, place the Diamond Station in "MANUAL".
I I CRs I Direct the crew using Annunciator Corrective Action 1203.012F for the SASS Mismatch alarm.
I 1 CBOT CBOR I Verify the signal from the non-selected instrument is a valid good signal on PMS.
When directed. select the opposite instrument for Loop "A" Thot on C03 1 CBOR 1 Verify the proper response to the selection of the good instrument.
Y CRS CBOR Direct the crew to slowly adjust control rods and feedwater to restore Tave back to the desired value.
Slowly adjust feedwater demand stations and control rods to return Tave to
-579°F.
u I I Event Termination:
Next event I .-
Appendix D Required Operator Actions Form ES-D-2 (This may require placing the SGlRX Master to "HAND")
approximately equal.
A. Rod Controller (Diamond Panel), ifapplicable
- 0. Reactor Demand C. Feedwater Loop Demands D. Load Ratio AT-cold E. SGlRX Master Page 8 of 13
Appendix D Required Operator Actions Form ES-D-2 NOTE: The CRS may also direct the placement of the SGlRX Master station to "HAND",but is not
Appendix D Required Operator Actions Form ES-D-2 associated with electrical distribution and AMP meters on C10.
Verify Backup Air Side Seal Oil Pump P-25 running.
Operations (1107.001) to determine any additional components that may
Appendix D Required Operator Actions Form ES-D-2 Direct immediate actions per the Reactor Trip Procedure, 1202.001.
the CRS when asked.
Direct operations per 1202.007.
frequency and foading:
4100 to 4200V 59.5 to 60.5 Hz
Appendix D Required Operator Actions Form ES-D-2 time delay (P4A, B, C).
CBOR Actuate MSLl for both SGs AND verify proper actuation and control of EFW and MSLl (RT 6): Identify that the remote switch matrix will not work to actuate MSLl for either OTSG on either train.
(Tech. Spec. 3.3.12 Emergency Feedwater lnitiation and Control (EFIC)
Manual Initiation)
Two manual initiation switches per actuation train for each of the following EFlC Functions shall be OPERABLE:
- a. Steam generator (SG) A Main Steam Line Isolation;
- b. SG B Main Steam Line Isolation; and
CRS Direct the CBOR to manually close the MSlVs and MFlVs on panel C09 or use the trip modules in the EFlC cabinets to actuate MSLl for both OTSGs.
CBOR Close the MSlVs and MFlVs for both OTSGs using the handswitches on C09 OR go to the EFlC cabinets and actuate MSLl for both OTSGs on both trains on the trip modules. Verify the actions per RT6 steps C. and D.
CRS Check RCS press remains 21700 psig AND PZR level remains 230.
CBOT Isolate Letdown by closing either:
Letdown Coolers Outlet (CV-1221)
OR Letdown Cooler Outlets (CV-1214 and 1216).
-Continued-
Appendix D Required Operator Actions Form ES-D-2 (Tech. Spec. 3.8.1.6, Two diesel generators (DGs) each capable of supplying one train of the onsite Class 1E AC Electrical Power Page 13 of 13
UNIT I SHIFT RELIEF SHEET Page 1 of 2 Computer Generated Form (ref. 1015.015)
DAT : 9/13/2005 ONCOMING SHIFT. Days CREW YOU= MMNTTWUN . RED PLANT POWER : 70% PLANTMODE ' 1 DAYS ON UME ' 250 CHEDULU)RISK: MINIMAL
... .- L- -.... .- . ._. ..........A power maneuver will be performed wing the Integrated Control System (ICS). Contingency Reactivity Plans are-.?
located in the Plant Data Book and at ANONJlOPSlAPPSlContingency
........ ...-.-.. .RX Plans.
ACTION STATEMENTS I N EFFECT (TS/TRM/ODCM/FS ETC)
None CONTROL ROOM ALARM STATUS K05-A5 MSRiT40 CRITICAL DRN TROUBLE
.z:>~:
a<$.>,:>K>z<$&:>, .....
EVOLUTIONS I N PRO(iRES5 70% power holding for the start of P8B (2ndheater drain pump). Heater Drain 1106.016, section 16.0 through 16.19. Step 16.20 is ready to be performed and P8B tions for the start of P8B have been completed. Condensate Pump, P2A, is in P-T-L per the procedure "MANUAL".
Power escalation to 100% in progress following maintenance to the "A" MFW a lnjec ion control valve is in hand.
Small fuel leak based on RCS isotopic analysis for Cycle 19.
WMC/FIN REQUESTS Power escalation to 100%
UNIT I SHIFT RELIEF SHEET Page 2 of 2 Computer Generated F o n (ref. 1015.015)
CHEMISTRY / Malntaln >30# hydrogen pressure m the Makeup Tank.
OTHER UNIT IMPACT None SWTCHYARD ACnVtTIES COMPENSATORY ACTIONS . None SPP OnMTii r I OFF-GOING SHIFT SIGNATURE CRSISM
ADDendlx D Scenario 2 Form ES-D- 1 er; Equilibrium xenon per 1104.002, Section 19.2.
concentration 2 CV1008 . I 2 C (CBOR) Pressurizer Spray Valve fails open 3 FW087 C (CBOT) Heater drain pump " B bearing heat up resulting in need to trip the pump. Pump will trip if no action is taken. (2 min.15 sec.- alarm, 3 min. 15 sec. -trip) 4 NIA R (CBOR) Lower power to -70% in response to a trip of a heater drain pump 5 Dl-lCC0009L C (CBOR) ULD station fails to lower demand signal in manual False 6 TR049 0 I (CBOR) Pressurizer level transmitter fails low 7 RCOOl M (ALL) OTSG tube leak progressing to a -150 gpm.
(.325) R20:OO R 8 Dl-H15C C (CBOT) H I feeder breaker from SU#1 transformer fails to False close when transferring auxiliaries.
9 CO-P75 C (CBOT) P75 will not start
- (N)omlal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 13 i f
Aooendtx D S c w r ~ 2o Form ES-D-1 Scenario #2 Objectives
- 1) Evaluate individual response to a feedwater and condensate system component failure.
- 2) Evaluate individual response to an Integrated Control System failure.
- 3) Evaluate individual response to a transmitter signal
- input failure to a controlling function.
- 4) Evaluate individual response to an electrical breaker failure
- 5) Evaluate individual response to an OTSG tube leaklrupture.
- 6) Evaluate individual ability to lower plant load in accordance with plant procedures.
- 7) Evaluate individual ability to operate controls to equalize boron concentrations between Reactor Coolant System and Pressurizer.
- 8) Evaluate the individual response to a failure of the RCS pressure or inventory control system component SCENARIO #2 NARRATIVE The scenario begins with an expected call from Chemistry to report the results of routine RCS sampling. The report informs the crew that a difference of 55 PPM exists between the RCS and the Pressurizer, requiring equalization to be performed to get the concentrations within 50 PPM. The crew will perform an RCSIPressurizer boron equalization.
Using a compressed time line, Chemistry will call an inform the crew that the difference between RCS and Pressurizer boron is 5 PPM and the equalization can be secured, as they desire. The crew will take the actions to complete the equalization. As the Pressurizer spray valve is attempted to be closed, the operator will report the valve will not close and RCS pressure is continuing to decline. The crew should take the actions for a Pressurizer spray valve failure using AOP 1203.015 for guidance.
The "8" Heater Drain pump bearing will begin to heatup and cause an annunciator alarm.
The crew will respond to the alarm by checking for the affected pump and taking actions to stop the pump. The pump may trip before the crew can stop it, and the CRS should direct a plant power reduction to stay within the high level dump capacity of the affected heater drain tank. As the crew is performing a power reduction, the operator will report the ULD station, being used to perform the power reduction, will not respond to his command. The CRS should direct the operator to use the SGlRX Master station to perform the power reduction.
The selected pressurizer level transmitter will fail low. The crew will take action to select the redundant transmitter for indication and control .
Page 2 of 13
WndixD Scenario 2 Form ES-D-1 SCENARIO #2 NARRATIVE (continued)
The power maneuver will cause a tube in the " A OTSG to begin leaking and progress to a rupture of -150 gpm. The crew will respond to the " A N16 Alarm and begin taking the actions of AOP 1203.023, Small Steam Generator Tube Leaks. The leak will exceed 10 gpm and require the crew to transition to the OTSG Tube Rupture EOP. The crew will begin a controlled plant shutdown.
At -50% power, when plant auxiliaries are being shifted to startup transformer, the operator will report the feeder breaker from SU#1 to the H I bus will not close. The crew must make a decision to either place the H I bus on SU#2 or remove the handswitch from SU#2 out of Pull-To-Lock and allow the bus to transfer to SU#2 automatically when the unit is tripped.
The crew will continue with the shutdown and at -12% power trip the unit. The CIW should begin a plant shutdown at 5 100°F/Hr. When directed to place the Auxiliary Feedwater Pump in service the pump will fail to start. This will require the crew to initiate EFW and continue the cooldown using EFW as the feedwater source until the Auxiliary Feedwater Pump is made available.
The scenario will be terminated when a cooldown is in progress and EFW is in service.
Aaoendix D Scenario 2 Form ES-D-1 Simulator Instructions for Scenario 2 samples with a 55 PPM difference.
Equalize RCS/Pzr boron concentration 2 T=15 IMF CV1008 .I2 Pressurizer Spray Valve fails open (Use a value of .I0 if the red light is not lit when the spray valve is opened) 3 T=20 IMF FW087 N/A Heater drain pump " B bearing heat up resulting in need to trip the pump. Pump will trip if no action is taken. (2 min.15 sec.- alarm, 3 min. 15 sec. -trip) 4 N/A NIA NIA Lower power to -70% in response to a trip of a heater drain pump 5 N/A IOR False ULD station fails to lower demand signal Dl-lCC0009L in manual 6 T=35 IMF TR049 0 Pressurizer level transmitter fails low 7 T=40 IMF RCOOl ,325 OTSG tube leak progressing to a -150 R20:OO gpm.
8 Pre- IOR False H I feeder breaker from SU#1 transformer loaded DI-HI 5c fails to close when transferring auxiliaries.
9 Pre- IRF CO-P75 OFF P75 will not start loaded Page 4 of 13
Appendix D Required Operator Actions Form ES-D-2 ROLE PLAY: Call as Chemistry and report RCS boron concentration is 782 PPM and Pressurize boron concentration is 837 PPM.
on the report from Nuclear Chemistry that the Pressurizer is >50 ppm higher than the RCS.
sing normal operations procedure 1103.005, direct the equilization of boron by ither method 1 or 2.
Place Pressurizer spray valve in manual and open slightly Place some Pzr heaters in manual and throttle spray flow to hold pressure Monitor RCS pressure closely.
ed Pzr heaters in manual and monitor RCS pressure closely.
Page 5 of 13
Appendix D Required Operator Actions Form ES-D-2 ROLE PLAY: Using time compression to complete the evolution, call as Chemistry and report the difference between RCS and Pressurizer boron is <5 PPM and equalization can be pressure continues to lower.
Valve Isolation, CV1009.
Page 6 of 13
Appendix D Required Operator Actions Form ES-D-2 T=20 CBOR Acknowledge and report Heater Dram Pump Bearlng Temp HI alarm, K06-E8 CRS D~rectactlons per 1203 012E , Annunciator Correcttve Action for K06-E8 CBOT Check TR-2890 for the affected pump Determine and report P8B bearing temperature rtstng NOTE The crew may elect to stop the heater drain pump prlor to it tripplng due to the fault CBORl Report P8B, Heater Drain Pump, trlp CBOT CRS Dtrect operattons per ACA 1203 012E, K06-A8 (P8NB Flow Lo) and/or 1203 012E, K06-87 (Condensate Pump Autostart)
CBOR Commence reduct~onin unit load to -70% at -lO%lminute using the ULD CBOR Report to the CRS that the ULD wtll not change demand as requested CRS Dlrect the CBOR to place the SGlRX Master H/A statlon in "HAND" and lower power to -70% at -IO%/m~nute NOTE: In the manual mode on the SGlRX master, the operator has control of the rate the plant will change it is expected the operator will maintain the rate of change near the dlrected rate by the CRS CBOR Place the SGlRX master in "HAND" and slowly toggled down, checking to determine the rate directed by the CRS
-Cont~nued-Page 7 of 13
Appendix D Required Operator Actions Form ES-D-2 at or near setpoint. (Auto or manual)
Appendix D Required Operator Actions Form ES-D-2 (Tech Spec. 3.3.15.A, Post Accident Monitoring (PAM) Instrumentation.)
Appendix D Required Operator Actions Form ES-D-2 Appendix D Required Operator Actions Form ES-D-2 NOTE The CRS may elect to place H I bus on SU#2 transformer or remove the handswltch for SU#2 from P-T-L and allow the bus to transfer to SU#2 when the unit IS trlpped 1 Place both Feedwater Demand HIA Statlons In HAND 2 Adjust demands to zero 3 Place Reactor Demand HIA statlon in HAND 4 Adjust to control reactor power at 10-12%
CBOT When unlt IS 5180 MW open HP Turblne Dram valves on C02 CBOT When untt IS 5100 MW secure reheaters CBOR When reactor power IS 4 2 %
1 Select bad SG to lndtcate on Header press recorder 2 Check Turblne Bypass valves controlling header pressure 880-920 pslg 3 Verlfy plant auxlllar~eson SU1 CRS Check PZR Level >200"
-Continued-
Appendix D Required Operator Actions Form ES-D-2 1 CBOR Trip Reactor AND immediately adjust Header Pressure Controller setpoint to 45.
I I verify all rods inserted AND Reactor power dropping CBOT Verify Turbine tripped.
CBOR Check Turbine Bypass valves controlling OTSG pressure 950-990psig.
I Operate PZR heater and spray in hand as required to maintain RCS pressure low within the limits of figure 3.
Stabil~zePZR level 255" Ver~fyOTSG N16mon~torsselected to GROSS posttion.
D~rectthe CBOR to begin a cooldown at < 100" FIHr.
CT CBOR Place Turbine Bypass valves for the "6" OTSG in hand and adjust to inltiate and maintain a cooldown rate of ~lOO°FIHr.(Within 15 minutes of unit offllne)
/I / CRS I Direct placing the Auxiliary Feed pump, P75, in service.
CBOT Attempt to start P75 from the handswitch on C12. Report to the CRS that P75 will not start.
I CRS I Go To step 24 and direct the CBOR to actuate EFW and verify proper actuation and control (RT 5).
CBOR Actuate EFW and verify proper actuation and control (RT 5).
-Continued-Page 12 of 13
Appendix D Required Operator Actions Form ES-D-2 Page 13 of 13
4goendix D Scenario 3 Form ES-0-1 outlet valve CV1407 fails to open on ESAS
Aooendix D Scenario 3 Form ES-D-1 Scenario #3 Objectives
- 1) Evaluate individual response to component failures affecting cooling of the main turbine generator.
- 2) Evaluate individual response to input failures to the Integrated Control System.
- 3) Evaluate individual response to a loss of reactor coolant accident
- 4) Evaluate individual response to failure of automatic actuation systems.
- 5) Evaluate individual response to failure of Emergency Core Cooling System components.
- 6) Evaluate individual ability to maneuver the plant in accordance with plant procedures.
- 7) Evaluate individual ability to start and operate feedwater and condensate system components in accordance with plant procedures.
- 8) Evaluate individual response to failure of system or components associated with control of the secondary heat removal capabilities.
SCENARIO #3 NARRATIVE This scenario begins with the plant at 30% power with the "A" Main Feedwater Pump operating, and the lntegrated Control System in "AUTO" with the exception of the ULD (STAR Module) which is in manual to perform power escalation. When the crew accepts responsibility for the control boards, the first event will be a power escalation to 40%
power to place the "B" Main Feedwater Pump in service and split the feedwater loops.
As plant load is increased, a failure of the automatic control valve for control of Auxiliary Cooling Water to the Main Generator hydrogen coolers causes Generator gas temperatures to begin rising. The crew will respond to alarms associated with generator gas temperature monitor and take manual control of the ACW control valve and regain cooling of the hydrogen gas.
The crew will place the "B" Main Feedwater Pump in service and prepare to continue the power escalation.
After the Feedwater pump is placed in service ("AUTO") the selected "B" OTSG Startup Level transmitter will fail low requiring the crew to stop the Feedwater transient that occurs as the "B" Main Feedwater pump overfeeds the "B" OTSG. When the crew stabilizes the plant, they will select the good transmitter for control and place the ICS stations in "AUTO".
The "C" Circulating Water Pump, P3C, will experience an internal electrical failure that will cause the winding temperature to rise to alarm setpoint. The crew will respond to the alarms and take actions to secure the faulted pump or respond to the trip of the pump.
The idle pump should be placed in service. The crew should also monitor for loss of vacuum and lower plant load, if necessary, to stabilize vacuum.
Page 2 of 12
j ~ e n d i xD A Scenario 3 Form ES-D-I SCENARIO #3 NARRATIVE (continued)
A reactor coolant system leak on an HPI line will cause RCS pressure to begin to rapidly drop. The crew should identify the LOCA and trip the unit. The RPS will fail to perform an automatic trip if the low pressure trip setpoint is reached and will require the crew to manually trip the reactor. The normal reactor trip pushbutton will fail to trip the reactor and the operator will need to use the backup trip pushbuttons on C03. The reactor will trip and the crew will perform the immediate actions of the Reactor Trip EOP and identify the failure of the RPS to perform its function.
RCS pressure will drop to the ESAS actuation setpoint and ESAS will actuate. CV1407, the BWST outlet to the "Red" Train components, will fail to open. The crew should stop the ES pumps associated with the RED train until the valve can be manually opened locally. While performing verifications of proper actuation of components, the operator will discover a difference in flows on the only operating HPI loop and throttle the valve associated with high flow to within 20 gpm of the other flows.
The scenario will be terminated when the RED train is restored to operation following the opening of CV1407 and EFW is feeding both OTSGs.
Page 3 of 12
A~oendtxD Scenario 3 Form ES-D-I Simulator Instructions for Scenario 3 "B"OTSG startup level transmitter fails 5 T-45 IMF CW084 N/A P3C, Circulating Water Pump, winding temperature begins to heatup due to internal motor problem.
6 T-55 IMF RC464 2.5 LOCA- Leak on an HPI line inside R7:00 containment 7 Pre- RP246 NIA RPS fails to trip the reactor automatically Loaded on a valid RPS trip setpoint. The RP247 NIA "Manual"trip button on C03 fails to RP248 NlA perform a reactor trip. (The backup RP249 NIA pushbuttons on C03 must be depressed IOR False to complete a reactor trip)
Dl-lCC0020 8 Pre- IMF CV1407 0 BWST outlet valve CV1407 fails to open Loaded on ESAS signal
Appendix D Required Operator Actions Form ES-D-2 CBOR Monitor Heat Balance power on plant computer polnt XPP Compare Heat Balance power wlth nuclear instrumentation CBOT Place Moisture Separator Reheaters in service CBOR Acknowledge and report annunciator KO4 66 in alarm (Generator 1-12Temp HI)
CRS Provlde direction per 1203 012C, Annunciator Correctwe Action CBOT Monltor recorder TR-9001 and/or PMS dynamlc alarm display for rlsing temperatures on the main generator CBOT CheckNerlfy CV4018, Generator Hydrogen Cooler outlet control valve on C19, operating properly CBOT Report the hydrogen cooler outlet control valve is closed CRS Dlrect the CBOT to attempt to manually operate the valve from the controller on C19
Appendix D Required Operator Actions Form ES-D-2 TR-9001 for signs of generator winding degradation.
Page 6 of 12
Appendix D Required Operator Actions Form ES-D-2 Anticipatory Reactor Trip System (ARTS) Reset" for the 2nd MFWP.
Discharge pressure, if available Suction flows on Feed Pumps Recirc HIA stations
Appendix D Required Operator Actions Form ES-D-2 gain control of feedwater flow.
station in "AUTO".
Page 8 of 12
Appendix D Required Operator Actions Form ES-D-2 for the circ water pumps.
NOTE: The "C"Circ Water Pump may trip before the CRS can direct the pump be stopped.
Page 9 of 12
Appendix D Required Operator Actions Form ES-D-2 governor valves closed CREW Recognize the actuation of ESAS on low RCS pressure CRS Transition to ESAS procedure, 1202 010, and direct crew operations
-Continued-
Appendix D Required Operator Actions Form ES-D-2 IA OPERATOR NOTE: When the WCO is sent to manually open CV1407, open the valve.
IMF CV1407 1 240
Appendix D Required Operator Actions Form ES-5-2 UNIT I SHIFT RELIEF SHEET Page 1 of 2 Computer Generated Fom (ref. 1015.0f5)
LXTE : 911412005 ONCOMING SHIFT. Days CREW : Voum U N TW N: RED PLANTPOWER: 30% PUNT MODE: 1 DAYS ON UNE : 250 CHEDULED RISK: MINIMAL n Makeuo No Concentration Chanae Reactivity change Last Shift 2 ppm / Dilution / 172 gals I Water I Anticipated reactivity change for oncoming shift / 2 ppm I Dilution 1 172 gals / Water
/ Delithiation performed last shift 1 / / -../ ... No /
I No minutes Delithiation required oncoming shift minutes I L Any unplanned power maneuver will be performed using the Integrated Control System (ICS). Contingency Reactivity Plans are located .in.-
the Plant.Data
.-. Book . and at ..ANONJIOPSlAPPSlContingency
. ...-. - . -. RX
... Plans.
ACTION STATEMENTS I N EFFECT (TS/TRM/ODCM/FS ETC)
None CONTROL ROOM ALARM STATUS Annunciators associated with 30% power ICS in Automatic at -30% power following a mid-cycle shutdown.
Power escalation is in progress per the Startup and Power Operations procedures.
"A" MFW pump is in service and " B MFW pump is running at minimum speed.
CV1207 seal injection control valve is in hand, None .dT CHEMISTRY Malntaxn >30# hydrogen pressure In the Makeup Tank.
UNIT 1 SHIFT RELIEF SHEET Page 2 of 2 Computer Generated Form (ref. 1015.015)
OFF-GOING SHIFT SIGNATURE CRSlSM
ADDendlx D Scenar~o4 Form FS-D-1 100% Power, Equilibrium Xenon CV1207, Seal Injection control valve, is in manual due to oscillations of seal injection when in 2 BAT ES19-2.txt C (CBOT) Condenser vacuum leak caused by the failure of (Batch fiie that creates the #5 turbine bearing gland seal regulator.
this condition) 3 NIA R (CBOR) Power reduction to stabilize vacuum 4 CV097 C (CBOT) Operating MUlHPl pump experiences high winding temperature and causes the pump to trip. The standby pump has no oil indicated in one of the oil bubblers and must have oil added prior to start.
5 BAT I(CB0R) CRD position indication faulty with a CRD WID crd-asym.txt inhibit (Batch fiie that creates this wndition) 6 MSf43 M (ALL) Main steam safety valve associated with '6' OTSG MS134.4 experiences structural failure and lifts. Steam Leak significant to warrant manual reactor trip.
7 TU155 C (CBOT) The main turbine fails to fully trip when the unit is TU156 tripped. One governor valve and one throttle valve fail to close, requiring the crew to shut the MSlV from the affected OTSG.
8 CV2648 C (CBOR) EFW valves to "B" OTSG from P7B fail open and CV2626 will not close from the handswitches.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
BBoendix D Scenario 4 Form ES-D-1 Scenario #4 Objectives
- 1) Evaluate individual ability to perform an RCS delithiation in accordance with plant procedures.
- 2) Evaluate individual ability to perform a plant power reduction and stabilize the plant in accordance with plant procedures.
- 3) Evaluate individual response to faulty control rod position indication.
- 4) Evaluate individual response to a loss of condenser vacuum.
- 6) Evaluate individual response to a main steam line break/overcooling event.
- 7) Evaluate individual response to failure of the main turbine steam valves to close on a turbine trip.
- 8) Evaluate individual response to a failure of Emergency Feedwater System components.
SCENARIO #4 NARRATIVE The scenario begins with the crew responding to annunciator alarms associated with the Control Drive System. The "Control Rod Asymmetric" and "CRD Withdrawal Inhibit" alarms are received and the crew will refer to the respective Annunciator Corrective Action procedures for direction. The ACAs will direct the crew to the "CRD Malfunction" AOP and the crew will begin diagnosing the situation. It should be determined by the crew that the condition is caused by faulty indication for Group 2, Rod #4. The crew will perform the actions required for a faulty control rod indication problem and bypass the alarm function for that rod. This will allow the crew to reset the asymmetric condition and regain control of the movement of the rods inhibited by the asymmetric condition.
Chemistry will call the control room and request they perform the 5 minute delithiation or the RCS that was anticipated at turnover. Chemistry will inform the crew that the idle Purification Demineralizer is 65 PPM boron higher than the current RCS boron concentration. The crew will refer to the Makeup and Purification procedure, 1104.002, and perform the actions for RCS Delithiation.
Condenser vacuum will begin to slowly decline and annunciators associated with the main turbine bearing #5 gland seal will alert the crew of a problem with the gland seal supply to the #5 bearing. The crew will respond to the ACA for the #5 bearing gland seal and "Loss of Condenser Vacuum" AOP. The crew will reduce plant load to stabilize vacuum. Gland sealing steam will be restored to the bearing gland and the vacuum will recover.
The operating makeup pump will experience rising motor windings temperatures due to an electrical fault in the motor. The crew will be prompted by an annunciator alarm and respond to stop the affected pump and start the standby makeup pump. The pump may trip prior to stopping and the crew should refer to the AOP for "Loss of Reactor Coolant Makeup", 1203.026. The standby pump will be placed in service.
ADDendix D Scenario 4 Form ES-D-1 SCENARIO #4 NARRATIVE (continued)
The crew will receive an "MSSV OPEN" annunciator alarm. Verification using the SPDS will identify one MSSV on the "B" main steam line open and the crew will dispatch an operator to confirm steam releasing from exhaust piping in the penthouse area. The operator will report not only steam from the exhaust piping but steam releasing from the sides of the penthouse structure, indicating a significant size steam leak. The crew will determine the leak sufficient enough to trip the unit and begin isolation of the affected OTSG. During the isolation process, the crew discovers Emergency Feedwater is still being supplied to the affected OTSG and must take action to stop the flow of feedwater to stop the overcooling that is occurring as a result of the continuous feed. The crew will have to stop the electric driven EFW pump, P7B, to stop the flow of EFW to the "B" OTSG.
This will allow the OTSG to boil dry and terminate the overcooling.
mndixD Scenario 4 Fom ES-D-1 Simulator Instructions for Scenario 4 Operating MUlHPl pump experiences 4 T=30 IMF CV097 NIA high winding temperature and causes the pump to trip. The standby pump has no oil indicated in one of the oil bubblers and must have oil added prior to start.
5 T=40 BAT NIA CRD position indication faulty with a CRD crd-asym.txt WID inhibit Main steam safety valve associated with 6 T=60 IMF MS143 6 'B' OTSG experiences structural failure IMF MS134 .4 and lifts. Steam Leak significant to warrant manual reactor trip.
The main turbine fails to fully trip when 7 Just IMF TU155 100% the unit is tripped. One governor valve prior to IMF T U I ~ ~ 100% and one throttle valve fail to close, time of requiring the crew to shut the MSlV from trip the affected OTSG.
Pre- IMF CV2648 1 EFW valves to "B"OTSG from P7B fail loaded IMF CV2626 I open and will not close from the 8
handswitches.
Page 4 of 13
Appendix D Required Operator Actions Form ES-D-2 1203.045, Rapid Plant Shutdown.
NOTE: After -3 minutes from the time the A 0 was directed to investigate #5 bearing seal pressure, restore gland seal steam to #5 bearing.
IRF GS6826-1 1 DMF MC088 Page 6 of 13
Appendix D Required Operator Actions Form ES-D-2 Appendix D Required Operator Actions Form ES-D-2 WDG TEMP HI.
NOTE: If the running MIU pump trips before the crew stops it, the following actions should be performed:
Tech Specs. 3.5.2.A ECCS Operating Page 8 of 13
Appendix D Required Operator Actions Form ES-D-2 Close Letdown Cooler Outlets (RCS) (CV-1214 and CV-1216).
RC Pumps Total INJ Flow (CV-1207)
Pressurizer Level Control (CV-1235)
Appendix D Required Operator Actions Form ES-D-2 A. IF seal bleedoff temperature is >180"F, THEN establish and maintain 8 to 12 gpm RCP Seal Total Injection Flow until ~180°F.
B. WHEN seal bleedoff temperature is <180"F, THEN adjust CV-1207 for 30-40 C. Place CV-1207 in AUTO. (The crew may leave in "MANUAL" due to operational guidance Page 10 of 13
Appendix D Required Operator Actions Form ES-D-2 Malfunction Action) and direct the crew actions.
BOR to RESET the Asymmetric Fault using 1203.012G, K08-A2, Page 11 of 13
Appendix D Required Operator Actions Form ES-D-2 ROLE PLAY: Call as the A 0 and report steam coming from the MSSV piping and coming from the sides of the penthouse.
all rods inserted and reactor power the valves to close.
-Continued-Page 12 of 13
Appendix D Required Operator Actions Form ES-D-2 UE 3.1 Uncontrolled OTSG Depressurization Resulting in MSLl Page 13 of 13