Text

Final - Section a Operating
	ML031200138
Person / Time
Site:	Indian Point
Issue date:	04/01/2003
From:	Wilson F; Entergy Nuclear Northeast
To:	Conte R; NRC/RGN-I/DRS/OSB
	Conte R
References
	50-247/03-301 50-247/03-301
	Download: ML031200138 (151)
	v • d • e

ES-301 Administrative Topics Outline Form-ES-301-1 Facility:

Indian Point 2 Date of Examination:

3/17/2003 Examination Level:

SRO Operating Test Number:

1 Administrative Topic/Subject Describe method of evaluation:

Descriptionl

1. ONE Administrative JPM, OR

2. TWO Administrative Questions A.1a Conduct of 2.1.7 Ability to evaluate plant performance and make operational Operations judgments based on operating characteristics, reactor behavior, and instrument interpretation. (3.7/4.4)

JPM:

Review a QPTR calculation and direct appropriate actions A.1b Conduct of 2.1.18 Ability to make accurate, clear, and concise logs, records, status Operations boards, and reports. (2.9/3.0)

JPM:

Review Control Room Log Entries A.2 Equipment Control 2.2.17 Knowledge of the process for managing maintenance activities during power operations. (2.3/3.5)

JPM:

Review (for approval) a completed surveillance for Tech Spec required equipment A.3 Non-Emergency 2.3.4 (3.1)

Knowledge of radiation exposure limits and contamination dose limits control, including permissible levels in excess of those question authorized.

QUESTION: Given the plant in a SAE and a personnel exposure history, determine the exposure limit for a Non-Emergency operation.

2.3.2 (2.9)

Knowledge of facility ALARA program.

EmergencyI Exposure Limits QUESTION: Given a situation requiring valve alignment verification in a Question radiation area, determine the waiver requirements for independent or concurrent verification of a locked valve and identify an alternate process for verification.

A.4 Emergency Plan 2.4.41 Knowledge of the emergency action level thresholds and classifications. (4.1)

JPM:

Classify the event Form ES-301-1 SRO ADM Outline NUREG-1021, Revision 8

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility:

Indian Point Unit 2 Task No.:

N/A Task

Title:

Perform A QPTR Calculation And Direct Appropriate Actions JPM No.:

2003 NRC Ala SRO K/A

Reference:

039 A2.01 (3.2)

Examinee:

Facility Evaluator:

Method of testing:

NRC Examiner:

Date:

Simulated Performance:

Classroom X

Simulator Actual Performance:

Plant X

READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

The plant is at 100% power.

NIS power range channel N-41 is out of service.

Task Standard:

Required Materials:

General

References:

Handouts:

Initiating Cue:

Determines QPTR outside of TS limits and initiates corrective action IAW Technical Specifications SOP-15.3 Rev 16 DSR 4B Calculator SOP-15.3 Rev 16 DSR-4B Partially completed DSR-4B The Shift manager has directed you to calculate QPTR manually using the given detector currents in accordance with the appropriate procedure, determine if the calculated values meet Technical Specification limits, and any appropriate actions to take, if necessary Time Critical Task:

NO Validation Time:

20 Minutes NUREG 1021, Revision 8, Supplement 1

Appendix C Page 2 of 5 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Note: The purpose of this JPM is to have the candidate calculate QPTR and to correctly apply the TS actions. The candidate will be provided a DSR-4B with upper and lower NIS detector currents already filled out.

Performance Step: 1 Standard:

Comment:

Performance Step: 2 Standard:

Obtain SOP-15.3 Obtains procedure Cue: Hand candidate a copy of partially filled out DSR-4B Record top and bottom detector currents Refers to DSR-4B for currents Comment:

Performance Step: 3 Standard:

Record date, time, and average reactor power Records on DSR-4B Comment:

Performance Step: 4 Standard:

Divide each detector current output by corresponding normalization factor Locates normalization factors and divides. Will only use 3 detectors, so denominator will be 3 Comment:

Performance Step: 5 Standard:

Calculate average normalized ratio for top and bottom detectors Performs calculation Comment:

NUREG 1021, Revision 8, Supplement 1

Appendix C Page 3 of 5 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 6 Standard:

Calculate Quadrant Power Tilt for top and bottom detectors Performs calculation Comment:

Performance Step: 7 Standard:

Record Highest Quadrant Power Tilt and appropriate signatures Records and signs DSR-4B Comment:

Performance Step: 8 Standard:

Comment:

Performance Step: 9 Standard:

Document results Enters data on DSR-1 Cue: DSR-1 entry made be made later Determine requirements of TS 3.10.3 are NOT met Refer to TS 3.10.3 and determine that QPTR exceeds 1.02 and determine that a power reduction is necessary Comment:

Terminating Cue:

When the candidate has determined appropriate action per TS, the evaluation for this JPM is complete NUREG 1021, Revision 8, Supplement 1

Appendix C Page 4 of 5 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.:

IP2 2003 NRC Ala SRO Examinee's Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result:

SAT UNSAT Examiner's Signature:

Date:

NUREG 1021, Revision 8, Supplement 1

Appendix C Page 5 of 5 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

The plant is at 100% power.

NIS power range channel N-41 is out of service INITIATING CUE:

The Shift manager has directed you to calculate QPTR manually using the given detector currents in accordance with the appropriate procedure, determine if the calculated values meet Technical Specification limits, and any appropriate actions to take, if necessary NUREG 1021, Revision 8, Supplement 1

4Af4(')00 (

UNIT TWO QUADRANT POWER TILT CALCULATION SHEET DSR-4B Rev. 73 Preiou SNSC#2545 11//

(QT-16-6)

DATE:

rob y

SNSCREIEW D4Tj TIME:

fqdoLA3 1203 AVE REACTOR PWR.

J0o6 Agn (iRE)

DAE 53 fiT USING DETECTOR OUTPUT CURRENT APPROVED DATE-Current QT number and Normalization Factors provided by Reactor Engineer.

1.

Determine normalized ratios by dividing indicated detector current by normalization factor as follows:

Channel Det Current Nor Ratio Channel Det Current Nor Ratio 41 Top= 41T=

Cr r J

1.= ri(A 41Bottom = 41B-rl 2

6

=

r ev 42 Top = 42T =

27

°

/ 88.3_-_

42 Bottom = 42B -1t

=

t11=

43 Top = 43T = /'i I

PJ.Qii=

43 Bottom = 43B = %9 r..u i=

44Top=44T= f6.'

1.9Q=

44Bottom=44B=

,-&9o

/*JD=

2.

Determine the average normalized ratio for the top and bottom.

Average Normalized Ratio Top

ANRT = 41 T + 42T + 43T + 44T

4 Average Normalized Ratio Bottom = ANRB = 41 B + 42B + 43B + 441c 4

3.

Determine The quadrant power tilt ratio for the top and bottom by dividing the highest normalized power ratio for the top and bottom respectively by their respective average normalized ratio.

Quadrant Power Tilt Top = QPTT = Highest value of 41T. 42T. 43T. or 44T ANRT al

_a QPTT = ANRT=

==

Quadrant Power Tilt Bottom = QPTB = Highest value of 41 B. 42B. 431. or 44B ANRB Value =

QPTB= ANRB= *=

4.

The higher of the two quadrant power tilts should be less than or equal to the Technical Specification Limit of 1.0200.

Enter the Higher QPT(Top or Bottom) = _. _ _

Technical Specification Limit

=

1. 0 2 0 0 NOTES:

1.

If the quadrant power tilt exceeds the Tech. Spec. limits, the SM, OM, RE and GM-NPG shall be Informed ASAP.

2.

If one detector Is out of service, the three In service detectors will be used to compute the average normalized ratios (ensure denominators in step 2 are changed from 4 to 3).

RO:_

SM:

Page 1 of 1

UNIT TWO QUADRANT POWER TILT CALCULATION SHEET DSR-4B Rev. 73 PreviousSNSC#2545 1115198 (QT-16-6)

DATE:

obf y SNS EIE DATE TIME:

rdow I

-103o3 AVE REACTOR PWR:

/0o C)

A__0 E)

DATE Isms1--V -

USING DETECTOR OUTPUT CURRENT APPROVED DATE Current OT number and Normalization Factors provided by Reactor Engineer.

1.

Determine normalized ratios by dividing indicated detector current by normalization factor as follows:

Channel Det Current Nor Ratio Channel Det Current Nor Ratio 4lTop=41T=

MA NA 114&6= -(A 41Bottom=41B=

rd Ag/*.i.

d rA 42 Top = 42T =

8 42 Bottom = 42B = v v v - \\

r 8

= O."9 3?

43Top=43T= /O'f

(

=

jS.9o 8 R5 9 43 Bottom=43B= AB.

r 118_9=

____3 44 Top= 44T= /- -'9

/*J_15.9_=_L.

'OV _

44 Bottom =44B =

l rj113= O8 9 o

2.

Determine the average normalized ratio for the top and bottom.

Average Normalized Ratio Top

= ANRT =--A!4 42T + 4L T + 44T= o 0 3 So Average Normalized Ratio Bottom = ANRB dj6 4213 + 438 + 44i-0 99 '2%

3.

Determine The quadrant power tilt ratio for the top and bottom by dividing the highest normalized power ratio for the top and bottom respectively by their respective average normalized ratio.

Quadrant Power Tilt Top = QPTT = Highest value of 41T. 42T. 43T. or 44T ANRT Mnhiin= %.ovq91 QPTT= ANRT= 0o.9S3S

=_I

__S_

Quadrant Power Tilt Bottom = QPTB = Highest value of 41 B. 42B. 43B. or 44B Value 0

'9' 2-'?ANRB' QPTB = ANRB.o <dot<)

=__

__7

4.

The higher of the two guadrant power tilts should be less than or equal to the Technical Soecification Limit of 1.0200.

Enter the Higher QPT(Top or Bottom) = _. _ _

Technical Specification Limit

=

1. 0 2 0 0 NOQES:

1.

If the quadrant power tilt exceeds the Tech. Spec. limits, the SM, OM, RE and GM-NPG shall be informed ASAP.

2.

If one detector is out of service, the three In service detectors will be used to compute the average normalized ratios (ensure denominators In step 2 are changed from 4 to 3).

RO:

SM__

Page 1 of 1

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility:

Task

Title:

KIA

Reference:

Indian Point Unit 2 Review Control Room Log Entries 2.1.18 (3.0)

Task No.:

JPM No.:

N/A 2003 NRC Alb SRO Examinee:

Facility Evaluator:

Method of testing:

Simulated Performance:

Classroom NRC Examiner:

Date:

X Simulator Actual Performance:

Plant X

READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

Task Standard:

Required Materials:

General

References:

Handouts:

Initiating Cue:

Time Critical Task:

Validation Time:

The surveillances required by DSR-1 are complete for 0700 All corrective actions taken or in progress in accordance with DSR-1 DSR-1 Rev 91 DSR-1 Rev 91 Completed DSR-1 Rev 91 Review the log entries taken on the 1900-0700 shift for approval NO 15 minutes NUREG 1021, Revision 8, Supplement 1

Appendix C Page 2 of 4 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

NOTE: Candidate may identify deficiencies in any order.

Performance Step: 1 Standard:

Determines CST level is out of spec low Refer to TS 3.4.A.3. Determine TS minimum is met. Action to commence filling. Document by circling reading and informing SM (Any step of this JPM)

Comment:

Performance Step: 2 Standard:

Determines Containment Average Air temperature is out of spec high Refers to TS 3.6.C and commence action to restore Starts Containment FCU or raise service water flow Comment:

Performance Step: 3 Standard:

Comment:

Terminating Cue:

Determines 21 Si Accumulator pressure is out of spec low Refers to TS 3.3.A and commences action to restore pressure Enters the action statement of TS 3.3.A NOTE: Containment Air Temperature and CST level are out of spec but not inoperable per TS. 21 Accumulator is inoperable per TS When log review is complete, the evaluation for this JPM is complete.

NUREG 1021, Revision 8, Supplement 1

Appendix C Page 3 of 4 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.:

IP2 2003 NRC Al b SRO Examinee's Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result:

SAT UNSAT Examiner's Signature:

Date:

NUREG 1021, Revision 8, Supplement 1

Appendix C Page 4 of 4 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

INITIATING CUE:

The surveillances required by DSR-1 are complete for 0700 Review the log entries taken on the 1900-0700 shift for approval NUREG 1021, Revision 8, Supplement 1

SNSC Review:

DATE: 9/17/98 DATE: __________

iANk 2 0 W Approved:

END DATE 1900 - 0700 REM ARKS (USE attached sheet for additional space.)

5

.A+&ak-0700 - 1900 REM ARKS (USE attached sheet for additional space.)

see aocA a s 1 OAD 3 Middle of watch Key Chart Recorder walkdown completed by at least two of the; SM, CRU, QR WE AND RO review checked on DacA 15.

2ND RO SIGNATURE:

(+1)

OAD 3 Middle of watch Key Chart Recorder walkdown completed by at least two of the; SM, CRS, QR WE AND RO review checked on page 15. 2 /

CRS SIGNATUREJ? Q(

2ND RO SIGNATURE:

(+1)

CRS SIGNATURE:_

=

A=__

SM:

WE:

f SM:

CRS:

UNIT 2 CENTRAL CONTROL ROOM LOG Page I of 17 DSR 1 REV. 91

END DATE ALARMS (at the end of 1900 - 0700 watch)

NOTE (denoted by 4)

1.

IF log readings are taken by an Operator other than the person assigned the watch, the 2nd Operator SHALL sign the additional signature block.

2.

Readings SHALL be taken at specified intervals unless precluded by other duties, as per OAD 3 Plant Surveillance and Log Keeping.

COMMENT on the reason for any missed reading. WHEN a reading is NOT applicable, MARK N/A in box. USE O/S AND COMMENT on the reason OR SEC WHEN applicable. Any readings outside of Normal range for a Non-Tech Spec item SHOULD be questioned, logged first, THEN corrected IF feasible.

3 Any readings which exceed a Mm/Max value SHALL be logged first, red circled, corrected AND explained in the Remarks Section.

I 4.:,

II

5.

This log is to be used whenever TAVE is greater than 200'F.

6.

Recorder charts SHALL be updated each shift.

7.

LIST all alarm windows that are indicating at the end of 1900-0700 watch in space provided above OR on an attached sheet. EXPLAIN the reason for the alarm occurring; CONTINUE explanations on back of sheet IF more space is needed.

8.

Ic either 12 hr. OR 24 hr. comparison indicates a count rate increase that can NOT be explained by planned changes in RCS conditions (eg. dilution, heatup etc.), THEN OBTAIN an RCS Boron sample ASAP. IF the calculated ratio is less than 0,8 OR greater than 1.2, THEN RESET the HIGH FLUX SHUTDOWN alarm per SOP 13.2, Setting of High Flux at Shutdown Alarm. IF the Reactor is shutdown AND either of the two HIGH FLUX AT SHUTDOWN alarms are blocked QO out of service THEN RCS Boron sampling frequency SHOULD be increased to at least twice per day.

9.

IF river water inlet temperature as indicated in the CCR reaches 77"F, IMPLEMENT SOP 24.1.1, Service Water Hot Weather Operations.

IF river water inlet temperature monitor in CCR is 0/S. use back up monitoring per SOP 24.1.1. IF service water inlet temperature exceeds 94"F, COMMENCE Reactor Shutdown per T.S. 3.3.F.4.

10.

Deleted

11.

IF river water temperature recorder is NOT recording temperatures continuously, RECORD all operable inlet AND outlet temperatures on OCR display, at hourly intervals on supplemental log.

12.

An increase in RCS leakage may be Indicated by either an increased activity noted during the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months log interval OR by receipt of the Warn Alarm. IF an unexplained, increasing trend is noted OR the Wam Alarm annunciates, AND the alarm is NOT due to a known evolution, PERFORM an RCS leakage rate calculation per SOP 1.7, Reactor Coolant System Leakage Surveillance.

13.

Deleted.

14. The calculated average steam generator level is for normal, steady-state conditions. Only use 2 channels WHEN one is out of service and apply the 2 channel limit to the result.

15. The calculated average Is for normal, steady-state conditions.

16. Pressurizer Level SHALL be maintained on program +/- 4% (see Graph RCS 2).

17. MAINTAIN average TAVE on program. ( See Graph RPC 4).

18.

IF containment temperature exceeds 118°F, CONSULT SM for guidance. IF temperature exceeds 125-F, LOG VC Temps on hourly Supplemental Log AND CONSULT System Engineering to determine at what indicated temperature to begin a reactor shutdown per T.S.

3.3.F.4.

19. USE ARP SBF-1, window 3-2 alarm to verify less than 193". IF alarm is up. log >193" until Indication can be used to give actual level. IF the indicated level reaches 20 ft. EL action should be taken to determine whether water is in the sump QO whether an instrument problem exists. IF indication Is due to water in the sump, REFER to Tech Spec 3.1.F.2.d.(3)

20.

USE ARP SBF-1, window 1-3 alarm to verify Recirc. Sump level less than 35 ft.

21.

There are two MIN I MAX ranges for the SIG Wide Range level indicators:

Range A)

This range is used WHEN Reactor Power Is less than PR equal to 2%.

Range B)

This range Is used WHEN Reactor Power is greater than 2%.

22.

Condensate Storage Tank Level, Tech. Spec. requirement applies to the Low Level. Tech Spec. 3.4.A.3.

UNIT 2 DSR 1 J-D-

9nf 7 REV. 91 CENTRAL CONTROL ROOM LOU

END DATE

23. a.

IF CCW Hx outlet temperature exceeds 105'F, DIRECT Nuclear NPO to record charging pump fluid drive temperature reading every two hours on a Supplemental Log.

b.

IF CCW Heat Exchanger outlet temperature exceeds 105'F AND Plant Computer System is O/S, RECORD CCW temperature AND RCP bearing temperatures every two hours on Supplemental Log.

24. WCPS Surveillance SHALL be calculated on the 1900 - 0700 watch. Zero counters after readings.

IF a WCPS zone is to be worked on or calibrated, average the other 3 channels, red circle the result and note the reason. Tech Spec 3.3.D contains the guidance for WCPS out of service.

25. Charcoal filter hours SHALL be calculated on the 1900 - 0700 watch at midnight. ENSURE start AND stop times are logged in the CCR Log. WHEN charcoal Is replaced OR charcoal sample results are SAT, CHANGE total hours to zero. The 1900 - 0700 RO is responsible for completing the "Charcoal Filter Hours" Section of the previous day's log.

26. Testing of this Fire Alarm panel will illuminate only the trouble light, NOT the alarm light AND the panel buzzer should sound. Testing of this panel will also bring up an alarm on CCR panel SD, window 1-5.

27. WHEN filter reaches 600 hours0.00694 days 0.167 hours 9.920635e-4 weeks 2.283e-4 months , WRITE a Work Order to the Performance Monitoring Group to obtain sample per Technical Specification 4.5.E.3.

28. WHEN filter reaches 600 hours0.00694 days 0.167 hours 9.920635e-4 weeks 2.283e-4 months , WRITE a Work Order to the Performance Monitoring Group to obtain sample per Technical Specification 4.5.G.2.

29. WHEN filter reaches 600 hours0.00694 days 0.167 hours 9.920635e-4 weeks 2.283e-4 months , WRITE a Work Order to the Performance Monitoring Group to obtain sample per Technical Specification 4.5.F.3. RECORD Charcoal Filter Hours until 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months is reached. After 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months , log >720 on reading sheet. After filter sample is taken AND with concurrence from T&P, re-zero filter hour ciock.

30. Radiation Monitor purges SHALL be done on the 1900 - 0700 watch, WHEN logging process Radiation Monitor data, VERIFY monitor is active (indication NOT locked onto a single value).

31. CHECK Alarm Panel Annunciator Lights AND Alarm Horns ( IF equipped ). Any Alarms that do NOT clear as a result of this test SHALL be explained In the Remarks section. IF any Alarm Cans require change out, REFER to OASL 15.81, Annunciator Can Change Out AND ENSURE appropriate attachment is completed.

32, Testing of this Fire Alarm Panel will illuminate only the Trouble Light, NOT the Alarm light AND the panel buzer should sound.

Testing of this panel will NOT bring up an alarm on CCR Panel SD OR SM.

33. During startup OR low temperature operation, it Is possible for RCP Channel I Loop Flow to indicate >120%. In these cases RCP Motor Current should be used as the limiting value.

34. IF a Sequence of Events report Is collected for other than planned testing, CIRCLE / in red. MAKE a comment in the comment section AND NOTIFY the SM immediately. DOCUMENT the concern via a Corrective Action report.

35. Fire Water Storage Tank.

a.

IF the first segment of the bar graph Is flashing, the instrument loop has an open circuit ( 1 % below band).

b.

IF the digital display indicates (- - - - ), the instrument is under ranged ( 10% below span).

c.

IF the bar graph AND digital display are blank THEN one of the following has occurred:

1.

The indicator OR transmitter has failed.

2.

Power has been lost. ( Transmitter Ckt 13 / Indicator Ckt 11 both on L&P Panel PH)

36. Unit 1 Condensate Storage Tanks.

a.

The CST High Level Control Valve LCV-7816 will ciose on the following signals:

1.

Trip at 466 inches, increasing: Reset at 416 Inches, decreasing.

2.

Local Alarm at 481 inches, increasing; Reset at 476 Inches, decreasing.

3.

Conductivity Trip 0.8 pSiemens, increasing; local alarm at 0.7 pSiemens.

37. COMPARE with previous log readings for unexplained deviations.

38. COMPARE the Service Water Inlet Recorder reading to the local temperature indications for at least one condenser waterbox inlet as a qualitative check of the recorder.

39. WHEN Plant Computer System is inoperable PERFORM the following:

1.

CONNECT DVM to TP/P412A Turbine Press" (Channel 412A) in Rack Al AND RECORD Reading.

2.

CONNECT DVM to TP/P412B Turbine Press" (Channel 412B) In Rack A9 AND RECORD Reading.

3.

COMPARE readings. Maximum allowable difference Is 22.7 mV.

40. The discrete indicators ("sugar cube" lights) shall agree with their respective continuous level indicators to within approximately 1 Ft.

Elevation.

41.

In addition to qualitative checks, VERIFY monitor is active (indication NOT locked onto a single value).

UNIT 2 DSR 1 I

CENTRAL CONTROL ROOM LOG Page 3 of 17

TAN 20 m END DATE

42. VERIFY that reading is ABOVE "Min. Value". Readings of "0.OOE+0" that are NOT accompanied by a 'No CPM" condition OR periodic fluctuations below Min Value" are acceptable.

43.

RECORD Alarm setpoint THEN COMPARE the recorded Alarm setpoint value to the value given in the Operator Aid 'Monitor Backgrounds, Calibration Constants AND Setpolnt Limits".

44.

Data are to be compared to meteorological parameters obtained using IP-1016, Section 5.0 (Primary Tower). ENSURE comparison is made to data In the same time frame, In addition, the Wind Speed data (1im) from the Backup Tower is taken. The check of the B/U tower wind speed is a qualitative check ONLY. The 2 m/sec. does NOT apply.

Note that the primary tower data, using 5.3.5a, are in mites/hr direction degrees, AND temperature differential in Deg F. Data SHALL be converted to meters/sec AND proper Pasquill category for comparison; MPH x 0.447 = m/s AND Table 5.2.2 converts the temp differential to Pasquill category. The Pasquill letter printed on the output (Addendum 5.2) under WD3 is NOT to be used for comparison.

During lightwind speed conditions (speed LESS THAN 4 miles/hr) the direction difference may EXCEED 150 Deg due to meander, Emergency Planning section is to be contacted for parameter verification.

45. OBTAIN Vent Flow from R-27 Monitor AND from magnahelic in alleyway AND COMPARE the two readings. NPO will give reading in SCFM as long as their hand held computer is functioning. Otherwise Convert in. H2O Magnahelic reading as follows:

SCFM=7.12 x 10,000 in. H2O

46. Deleted

47. Record which FCU is currently being monitored, IF the WEIR level is high enough to indicate a flow rate on the display, USE graphs RCS 6-1, 6-2, 6-3, 6-4, OR 6-5 as appropriate to convert FCU condensate level to flow rate.

48. The Discrete, Redundant AND Continuous levels SHALL be consistent with each other AND be within 1 ft EL difference.

49. The NR reading SHALL NOT be more than 1 psig above the highest reading WR channel OR more than 1 psig below the lowest reading WR channel.

50. PERFORM a qualitative check for these steps by OBSERVING channel behavior, including any other available indication such as alarm AND failure lights, etc., to determine acceptability.

51. IF the Plant Computer System is unavailable for QPTR calculations, PERFORM a manual QPRT calculation per DSR 4B, Unit 2 Quadrant Power Tilt (Det. Curr.). IF required to log detector output voltages, ATTACH printed report from plant computer system to this DSR.

52. IF the Plant Computer System is unavailable for Delta I calculations, USE DSR 1A, Central Control Room Log (Reactor Delta I Critical Ops Only) to record these values.

53.

The normal and MIN/MAX limits assume both tanks are operable and reading in this range to satisfy Tech Spec level limits. IF one BAST is taken out of service, EVALUATE appropriate Tech Spec levels of the remaining tank using GRAPH TC-3, Boric Acid Storage Tank, and GRAPH TC-3A, Boric Acid Storage Tanks BAT21 and BAT22 Level Transmitters.

54. VERIFY that the Plant Computer System autologging comparison AND alarm functions of Analog RPls and Rod Bank Step Counters Is operable (Plant Computer System will actuate Panel SFF 2-7, CONTROL ROD OR POWER DISTRIBUTION TROUBLE, if the two indications do NOT agree within a programmed deadband). IF the Plant Computer System autologging OR IRPI Alarm Function is NOT operable, COMPLETE DSR 3, Unit 2 Rod Position Verification.

55 The Plant Computer System will generate a report displaying current Rod status, Position, etc. Attach this report to this DSR.

56 To verify the Plant Computer System alarm status is operating properly, OBSERVE alarm function screen using Tum-On Code ANNUN AND VERIFY there are no abnormal conditions.

57 IF less than three off site power supplies aligned to Ul L&P busses, REFER to U1 TS 2.5.1.1.

58 Reactor Power is determined by the Plant Computer System (PICS) On-line Heat Balance. NI upper limits and adjustments are controlled by SOP 15.1, Reactor Thermal Power Calculation.

59 VERIFY weekly PC Heat Balance results with PICS Heat balance. IF PC heat balance is Greater Than +/- 0.2 percent of PICS Heat Balance, CONTACT the IT PICS group. The PICS Heat Balance will continue to be used to calculate Reactor Power.

60 IF Station Auxiliary Transformer (SAT) Tap Changer unable to operate In Automatic, GO TO SOP 27.1.4, 6900 Volt System.

61 Per TS 3.10.5.1, the following limits apply:

Above 85 Percent Power Group Step Counter Demand Maximum Positive Deviation Maximum Negative Deviation (TS Table 3.10-1)

Position (Steps) teps Inches Steps Inches s 209 12 7.5

-12 7.5 210 to221 16 10

-12 7.5 222 16 10

-13 8.125 223 16 10

-14 8.75 224 16 10

-15 9.375 2225 16 10

-16 10 At or Below 85 Percent Power

+/- 24 steps. This equates to +/- 15 inches.

These comparisons are between the analog RPI and their associated Rod Bank Step Counters.

LONG TERM CORRECTIVE ACTIONS:

Incorporated TPC 01-0041 as a Long Term Corrective Action Into Revision 83 of this DSR. This TPC changes the Normal and Min/Max limits for Instrument Bus Voltage as follows:

NORMAL 117-120V MIN/MAX 117-122V This TPC will be removed following completion of CR 200101134 UNIT 2 DSR 1 UN 2 P

4of 17 REV. 91 CENTRAL CONTROL ROOM LVOi i, t T _

PARAMETER UNITS I NORMAL I Counts Per Second CPS Variable Ten Minute Count Counts N31

+ 8)

Current Counts/

6 HR Prev Counts Calc

< 1.2 Current Counts/

24 HR Prev Counts Counts Per Second CPS Variable Ten Minute Count Counts N32

+8)

Current Counts/

6 HR Prev Counts Calc

< 1.2 Current Counts/

24 HR Prev Counts N -35 INTERMEDIATE AMPS Variable RANGE N-36 IAN 2 Q M END DATE TIME MINI MAX 1900 0700 0700-1900 1

311 IE5 C

j 0.8 1.2 3/1E5S 0.811.2 YC3J 117 /122 3001481 3Y-Y-(25.40) 6*

3

(+38) 926~

(+38 (4ai

/U l

v)

INSTRUMENT BUS VOLTAGE 21 22 23 24 11 12 13 Volts AC 117. 120 Unit I CST

(+36)

Inches l

416 - 466 (Feet) 1 (34.7 -38.8)

I Unit 1 Inlet (01)

N/A SERVICE WATER TEMP (TR - 6281 )

Unit 3 Inlet (03)

South Disch (04)

Middle Disch (05)

North Disch (06)

Unit 1 2 & 3 Ave Inlet Temp (26)

N/A

. / 77 l

I DSR 1 REV. 91 UNIT 2 CENTRAL CONTROL ROOM LOG Page 5 of 17

EAN DATE-END DATE PARAMETER

] UNITS l

NORMAL l

MIN / MAX I

-0700 TIME 1900_

000 0700 - 1900 r

l jI G

E N

E R

AT 0

R E

MP E

R A

T U

R E

Cold Gas Cooler 21 (point 1}

Cold Gas Cooler 22 fpoint 3)

Cold Gas Cooler Delta T Stator Coolina Water In 7poin17)

°C 35 - 45 0-5 41 -45 41 - 73 30/46 0/10 38 / 46 38 / 75 Stator Cooling Water Out (point 8)

VC Air R - 41 MONITOR Particulate 41 )

(+ 12)

CONDENSER SALINITY HIGHEST S/G SODIUM R-28 R-29 MAIN STEAM LINE RADIATION MONITORS R-30 R-31 AIT-5092 T

Channel NH, 0

M I

AIT-5093 x

0 Cl2 I

N ClI T

AIT-5095 A

R Channel NH, S

2 AIT-5096 Cl3 R-38-1 CCR INTAKE VENT. RADIATION R-38-2 R-25 VC HIGH RANGE RADIATION MONITORS R-26 WIDE RANGE PLANT VENT R-27 MONITOR EFFLUENT MAGNAHELIC U2 PLANT VENT FLOW MONITOR R-27, Ml-29 CONTAINMENT SUMP Li - 3303 LEVEL REDUNDANT

.Ll

- 3304 MCI/cc PPB Variable 0-2 0 - 1 Variable

./ 4.9 0/5

/'0 6,

c2 2 T I

CPM PPM mR/hr R / hr pCI/sec SCFM EL

(+50) 0-5 0-0.5 0-5 0 - 0.5

(+50)

(+ 50)

N/A 0/ 10 0 /0.8 0 / 10 0 / 0.8 N/A LIUII I

h 73 1

)

H~

Ii I

/ 1

~I L I0

(+ 50)

N/A VERIFY PICS DELTA FLUX (DF display Is operable and updating properly. (Data is green)

Stator L

GE C~urrent B_

E Ap llN lMeter C

E R

A Stator Voltage T

0 Hydrogen Pressure R

Field Amps MAIN UNIT LOAD NET LOAD GENERATOR MVARS

/

1

/

NIA YL A

@~~~

C Xb 30 1,79S 1

/t <$

300 L4~

IN/A K-Amps l K-oi's l

P MW l

ll MVARl Variable 20 - 23 60 - 75

< 6000 Various I

I I.

DSR 1 REV. 91 Page 6 of 17 UNIT 2 CENTRAL CONTROL ROOM LOG

JMri ls',

q xeT.

END DATE l

l lTIME PARAMETER UNITS f NORMAL I MIN I MAX f1900 - 0700 TIME GOVERNOR CONTROL 40-45 35/50 LOAD LIMIT # 1 PSIG Governor Governsr Pressure

+5 pi L

LOAD LIMIT # 2

+1 psi MAIN STEAM HDR PRESSURE PSIG 625-995 0/

A 3 ST 412A TURBINE 1ST STAGE PRESSURE (Plant l 1

PSIG Variable f

Computer System) 412B PI-41 9A 21 STEAM LINE P7419C PSIG N/A=

Pl-429A PSI N/A' 7

PRESSURE PRSPl-429C li73

-T 3o Pl-439A

?°7 L

X 23 STEAM LINE Pi-4298 PSIG N/A 7 PRESSURE Pl-439A

)l STEAM GENE RATOR L (I49 z

4)Aeaeo X

4825 825 Ll-427A_

i

)

5 24STEAM LINERAO PI-449B

%SI 46/52 73 YG LEVEL-44C

(+14)

Average of 3 47. 2./57 43 4752.71 f

Operable channels 2: 48. /52.1 2: 48.3/52.1 UI T 1

2 DSR46

/52 17 C

LEVEL LIC4NO O

LG Pg 177C OSR4 AverageL CONRO ROMOGPae7.

of 37 47EV.521

JAN 2 0 MI END DATE I

ITIME PARAMETER UNITS NORMAL MIN / MAX 0

[

1 1900 - 0700 0700 - 1 900 Attach the Plant Computer s stem Control Rod Auto Log N/A l

VERIFY Plant Computer System Alarm Functions N/A

/

Operable ( + 56 )

PERFORM PC Heat Balance on Sunday N/A N/A

(+59)

'tJ f

PICS 8 Hour Reactor Power rolling ave (VERIFY S/G Blowdown Flow updated prior to taking reading)

-/E 3071.4 U1 1 18HR8 Mw 5 3071.4 l

I Analog RPI:

Shutdown Bank A High Low Analog RPI:

Shutdown Bank B Analog RPI:

Shutdown Bank C Analog RPI:

Shutdown Bank D Analog RPI:

Control Bank A Analog RPI:

Control Bank B Analog RPI:

Control Bank C High Low High Low High Low High Low High Low High Low Inches N/A Analog RPI:

Control Bank D High Low

'I I'

I Rod Pos Step Counters Shutdown Bank A, Group 1 U0053 FLT PnI Rod Pos Step Counters Shutdown Bank A, Group 2 Rod Pos Step Counters Shutdown Bank B, Group 1 Rod Pos Step Counters Shutdown Bank B, Group 2 Rod Pos Step Counters Shutdown Bank C Rod Pos Step Counters Shutdown Bank D Rod Pos Step Counters Control Bank A, Group 1 Rod Pos Step Counters Control Bank A, Group 2 Rod Pos Step Counters Control Bank B. Group I Rod Pos Step Counters Control Bank B, Group 2 Rod Pos Step Counters Control Bank C, Group 1 Rod Pos Step Counters Control Bank C, Group 2 U0053 FLT PnI U0054 FLT Pnl U0054 FLT Pnl U0055 FLT PnI U0056 FLT Pnl U0049 FLT Pnl U0049 FLT Pnl U0050 FLT PnI U0050 FLT Pnl U0051 W0Y

/39

/fr'

/16

/

/vy-

/vC

'1/

/32-I9/7r I9 /3 iTh (3&

K' LI 22L

)9z:3 Steps N/A FLT Pnl U0051 FL T Pnil UNIT 2 CENTRAL CONTROL ROOM LOG DSR 1 REV. 91 page 8 of 17

END DATE TIME PARAMETER l

UNITS NORMAL MAX 1900 - 0700

[

0700 -1900 U0052 Rod Pos Step Counters Control Bank D, Group 1 FLT Pnl 9zY) steps NA Rod Pos Step Counters U0052 Control Bank D, Group 2 FLT Pnl1 TI-411A TI - 421A 6Ga RCSTEMP N/A 6T INDICATORS TI - 431A TI-441A r

VI TI-412C

5Y7, TI-422C T -AVERAGE TI-432C

°F Variable Cl 4 17)

TI-442C 5S5ji Avg - T. Avg

_ Sl (

21 RCP

__I t

REACTOR 22 RCP 0

5 COOLANT

.GPM 1.0 - 3.0 0./

7 PUMP No. I SEAL Fl - 415 Fl - 46

%N/A..

FI-435

%N/A (0'

FI -4365c N/A Fl -4456/

921 RCP c

COOLANT 22RCP AMPS 380 - 410 350 / 450 PUMP 2

C MOTOR CURRENT 23 RCP 2

C, 24 RCP 390 21 RCP REACTOR 22 RCP INCHES COOLANT 30-100 5/-

PUMP THERMAL BARRIER 23 RCP WATER DELTA P 24 RCP

'D7 21 RCP l/1 REACTOR COOLANT 22RCP PUMP 22RPPSID

> 400 326/

No.10 SEAL 23 RCP DELTA P L)0 24 RCP 21 RCP REACTOR COOLANT 2

C PUMP 22RG F

80 -150 70/159 OUTLET 23 RCP TEMP.

24 RCP VESSEL FLANGE LEAKOFF F

6-1 3 0 50 / 140 DSR 1 IWNIT21 REV 91 I

CENTRAL CONTROL ROOM LOG r-d-:;

3 l

END DATE TIME PARAMETER UNITS NORMAL MIN I MAX 1900-0700 0700- 1900 21 RCP REACTOR COOLANT22RP7-2.

PUMP 22 RCP GPM 6-12 2 /20 INJECTION 23 RCP

_ 7 FLOW UT 2 DR 1 CNRALC PRESSURE PSIg 1

o 1 REV. 91 COTANMN SL)PlLl91 E

N/A

48) 9 LE-EL 69 -7sx kk5 67 77 PRESSURCAIZER SUMP LR5 - 33137L SS xx RECCLAIEF S

UPDSRETLl-99 3

S SUR PSI.S.S TE P

-E P

F 90 -120 4/5S 1ll LEVEL DICRT Li -C

)

ETNA 417 X555XXXXX CNRLCONTINOUS ELO LOG Pae40o 1 EV

END DATE I

MI I

lA TIME PARAMETER UNITS NORMAL MIN / MAX 1900-0700 TIM I

190 - 000 10700 - 1900 21 22 FAN COOLER UNIT SERVICE WATER 23 OUTLET FLOWS 24 25 21 WIDE RANGE STEAM 2

GENERATOR LEVELS 23

(+ 21 )

24 HOTWELL LEVEL LI-1131-1 (CCR)

PRIMARY WATER TANK LEVEL LIC-1101-S (Local)

- /orpo

/

1 C2 C7 GPM 1200 - 1600 1000 /1800 Variable A) 60 1 100 B) 45180

{I G ',D (C (Do0

/0 fbo (f(

f(&

<-s TSJ 5-3 2e. Ž a( - a 2 6. IS

{( f ::o I

IL I <: O S- (

. 1t FEET

_I

[I CHARGING LINE FLOW GPM 30-*45

-/

Z TEMP.

°F 122 - 127 100/145 Lz3 FLOW GPM 82 - 88 40/ 122 8 2..

8 PRESSURE PSI 225 - 275 225 /400 2Q.3 Z

VOLU PRESSURE PSI 15-25 15/65 P

TANTL LEVEL 21.4 -35 21/ 91 C

Heat Exchanger 7F 7

0 10 / 110R COMPONENT Outlet Temp F

72-100 7012HR5 C-2.....

COOLING Flow GPM 3000 - 4000 1500 /7000 3CO 3

Surge Tank Level 47 - 53 46/54 O

CONTAINMENT SUMP FLOW l

F - 3401 GPM N/A

(+ 50)

O O

SUPERVISORY PANEL ANNUNCIATOR POWER LIT LIT LIGHTS

/

UNIT AUX TRANSFORMER VOLTAGE VOLTS 7050 - 7150 7000 7200 C7 STATION AUX TRANSFORMER VOLTAGE 7t*oo TOTAL AUX TRANSFORMER LOAD MW Various N/A 3jw

34 BUS 5A (o

GO STATION BUS 2A1 z

3 T SFRMER AMPS 40 - 150 0 / 200 TRNSORERBU 3 2-o i

480 V BUS AMPERAGEBU3 BS 6A

-7S s

_1 l f490 4

AJ 2,A L

6ERVCE W ER 2122-23 HDR PSI 60-80 581125 PRESSURE 24-25-26 HDR t

CONTAINMENT HF 65 - 80

-/95 DEW POINT LOW 37-DSR '

REV. 9 UNIT 2 CENTRAL CONTROL ROOM LOG Page 11 of 17

END DATE TIME 1900 -0700 0700 1900 DSR REV. 9 UNIT 2 CENTRAL CONTROL ROOM LOG Page 12 of 17

JAN _ 0 m END DATE PARAMETER MAX DIFF VALNUE UNITS CHANNEL ALARM SETPOINT 1900 -0700 98 PAB N/A NIA mRlhr R-5987 A

UNSAT Area Radiation NA m/r R58 A

NA CCR Area Radiation N/A N/A mR/hr R-1 I),

) 5 6

se)I UNSAT 80'VCO Area N/A N/A mR/hr R-2 DA /UNSAT Radiation Charing Pumps Area N/A N/A mR/hr R-4 I

C)

/

SA / UNSAT Radialtion FSB Area Radiation N/A N/A mR/hr R-5

/ C) 6 *

-SA-UNSAT Radiation Sampling Room Area N/A N/A mR/hr R-6 1

A UNSAT Radiation/

incore Inst Room Area N/A N/

Rh R7/0QSAT)

UNSAT Radiation N/A mR/hr R-7 COW ix 21 SW Outlet N/A 39OE 09 i

R-O

(

7 AT/UN3A Activity

(+41)

(+ 42) uc

(+ 43)

COW Hx 22 SW Outlet N/A 1.OOE-09 uCi/cc R-40 OO SAT L.

Activity

(* 41)

(+ 42)

(+ 43)5 SA~jT Containment Air N/A 1O0E-14 uCi/cc R-41 (0

/

436 )7UNSAT gas cti~t N/At O E-O u~icc

-42

(+*43 )

_______/

NSA Particulate Activity

(+ 41

(+ 42) uCi/cc 43 Containment Air Radio N/A 1OOE uCl/cc R-42

/

4

/ UNSAT gas Activity

(+ 41)

(+ 42)

(+43)

/

Plant Vent Particulate N/A 1.00E-14 uCiCc R-43

(

43 )

i' UNSAT Activity

(

41)

(+42) uicc (Part.)

(43

)

3Iioc 3C-U Plant Vent Iodine N/A 1.OOE-14 uCI/cc R-4 36 e 0

O

_/___ UNSAT Activity

(+ 41) 42 (Iodine)

((4

43) 2

42) tI Plant Vent Gaseous N/A 1.00E-09 uCucc R-44

(*43)

{

ST/UNSAT Activity

( + 41 )

(+ 42 )

u /

437 Discharge Condenser N/A (l*QE 09 3

1 OO R-45 3, 0 E

°F7

° 3 UNSAT SJAE Gaseous Activity

( +41 OO(+4 uCi/cc R-45

()

+3 SA IUNSAT FCU Service Water N/A 1.OOE-09 uCi/cc R-46 3K e Q I UNSAT Outlet Activity

( + 41)

(0+42 (4) 2C 43 G

N ACtWActivity N/A

(+42) uCi/cc R-47 S

AT S+

1 O

u c

42 )

(+ 4 3 )

2 _ _

WOS Liquid Effluent N/A 1.OOE-09 uCi/cc R-48 SAT l___

Activity

( + 41 )

( + 42)

(+ 43)

)AT/

SAT SG Blowdown Effluent N/A 1.0OE 09 u~/c R-49 i, vc, &7

/ N Ac4tivi4ty(+41)

+ 42) uCcc

(+ 43)

/

SAT UN Large Gas Decay Tank N/A 1,OOE-04 Ci R-50 5 0S I

UNSAT Activity

(+ 41 )

(+ 42)

(+ 43)0/

/A 1,OOE-09

/A 0 SBBPS Activity

(+41

(+42) uCi/cc R-51 IUNSAT SBBPS Cooling Water N/A i.OOE 09 R-52 c

R-5 Activity

(+ 41 )

(+42) uic(+

43)

INA FCU Service Water N/A 1.OOE-09 uCI/cc R-53 C)

Oc~ CN Outlet Activity

( + 41 )

(+ 42)

(4 43)

Y.0

~UNA Liquid Waste Distillate N/A 1.OOE-10 XI/cc R-54

'~

~/UNSAT Activity

( +41 )

(+42) 4 SG 21 Blowdown N/A 1.OOE-09 uCI/cc R-55A 1' 8 L£'

SATLA~

Activity

(+ 41 )

(+ 42)

(+ 43)

N/A 1OOE-0

~,

6e (3-SAT

/42gj SG 22 Blowdown N/ 41 OOE429 uCi/cc R-55B

+ 43 V

Activity (4)

(4)(4)_____

SG 23 Blowdown NA lE09 uCi/cc R-55C

/

5 "SA A

Activity

(+41 )

(+42)

_(+

43)

SG 24 Blowdown N/A 1.OOE-09 OL/c R55

,()

t-

/f SATI

/~

Activity

(+ 41 )

(+ 42) u(i/c 4355 Sewage Effluent Activity N/A 1.0OE-09 uCl/cc R-57

-UN (Ic SB)

(+ 41)

(+42)

(+43) 9USA DSR 1 REV. 91 UNIT 2 CENTRAL CONTROL ROOM LOG Page 13 of 17

END DATE PARAMETER MAX DIFF

_VMLNUE UNITS CHANNEL ALARM SETPOINT 1900 -0700 House Service Boiler N/A 1.OOE-O9 uCUcc R-59

(

0 9 Condensate Activity (4 41 )

(4 42 )

u(lc R-9o; 43)

Stack Vent Particulate N/A 1.OOE1 13 uc R-60

),0o-lo,-S--

C

~UNSAT Activity

( + 41 )

(

)

uCUcc (Part.)

(+ 43 )

?,

___C____UNSA Stack Vent Iodine N/A 1.OOE-14 R-60

(

/'

4 DA l'NSAT Activity

( +41)

+42 uCi/cc (IodIne)

(+ 43)

SC

,,UNSAT Stack Vent Noble Gas N/A 1.OOE-09 uCi/cc R76 U NSAT Activity

( + 41

(+42)

(Gas)

(+ 43 U

Sphere Foundation N/A 1.OOE-O9 uCi/cc R-096 w

+

)

_/

UNSAT Sump Activity (4+41)

(442) u+ic43-M____Bildg__ntNA1

__E__

(43

~/UNSAT Particulate Activity (4+41 )

( +42 )

u

(/cart.)

+LOt 4u3iVn NA 1OE1 Rce/NA M & 0 Building Vent N/A 1.OQE 09 uCi/

R-5976 01

/

~UNSAT Gaseous Activity

( +41)

(+42)

(Gas)

(43)

PARAMETER MAX DIFF j UNITS CHANNEL 1900 0700 l

RESULTS 122m 1016 S

/ UNSAT 122m CCR f

)

60m 1016 U

rb

/ UNSAT Wind Speed 2

M/sec 60m CCR

(+44) 1Om(pri) 1016 UNSAT 1 Om (pri)

CCR B/U inm (B/U)

Tower SAT/UNSAT 122m 1016 ACT U I

fSATI!UNSATI 122m CCR Wind Direction 90 Deg 60m 1016 UNSAT

(+ 44) 60m CCR 10m 1016

(

IUNSAT lo 1m CCR 1

10-122m 1016 U

_______I UNSAT Delta T Pasquill I letter 10-122m CCR (4+

44 )

CategoryI 10-60m 1016 O/UNSAT 10-60M CCR DSR I REV. 91 UNIT 2 CENTRAL CONTROL ROOM LOG Page 14 of 17

END DATE MIN/

PARAMETER UNITS NORMAL MAX 1900. 0700 0700-1900 CHART WORKING N/A i

/*

OAD 3 INKING N/A v

V KEY CHART PEN(S) ALIGNED N/A

/

RECORDERS TIME STAMPED N/A

/

DATED N/A

/

WCPS SURVEILLANCE (4+ 24)

CURRENT TIME:

6C 3

PR EVIOUS READING TIME:

r)fl TA HC)O IRS:

l Q 1. I I I -

RECORDER LEAK RATE

=

CFM 11 I I CHARCOAL FILTER HOURS ( + 25 )

FILTERS UNITS NORMAL MI/A RN TODAY i),cg3 +

Ir I_ A O1 -A I /

7, I

D

+

TOTAL HOURS AS OF 0000 THE PREVIOUS DAY 0

D CD

6=

TOTAL HOURS 7c~

C)

TSC I

Hours I

DSR 1 Page 15 of 17 REV. 91 UNIT 2 CENTRAL CONTROL ROOM LOG

JAN 2 0 2M3 END DATE EQUIPMENT J STATUS I UNITS l NUMBER 1900 - 0700 0700 - 1900 MAIN BOILER RPM,SEC, CIS 21 7

3 FEED PUMP SPEED RPM SEC. 0IS 22 22-c.-

21 CHARGING

% SPEED, SEC, 0/S 22 L((

PUMP SPEED 23 21 PRIMARY WATER PUMPS I/S(/), STBY, SEC, 0/S 22 22 5(8 21 22 FAN COOLER UNITS I/S (/), STBY, SEC, O/S 23 s'r3 '=

24 srW

&4 25 s r3V

__/_

21 O

rl) l HEATER DRAIN TANK PUMPS AMPS, SEC, O/S 22 21 (2

CONDENSATE PUMPS AMPS, STBY, SEC, OIS 22 23

~-o2 ONTAINMENT SUMP PUMPS STBY, AUTO ON, OFF, 29 S

o cA4h.)

COTIMN UPPMSHAN'D 210

'7?

21 COMPONENT COOLING I/S (/), STBY, SEC, O/S 22 WATER PUMPS_____

_23 ESSENTIAL S.W. HEADER

/

12,23,6 4

1,2,3 45,6 21 22_

23 SERVICE WATER PUMPS IIS (/), STBY, SEC, 0/S 24 25 I

26 LOW PRESSURE AMP, SBYSEC 0

RIVER WATER PUMPS AMPS, STBY, SEC. OIS 12 2______

ll 21 22 CIRCULATING AMPS, SEC, OIS 23 WATER PUMPS AMS E.0524 25

~ ~26 7

21 7

COMPONENT COOLING IIS SEC, O/S WATER HEAT EXCHANGER IS()SE./522 PURIFICATION LINE UP SFP/RWST SFP / RWST S__

LIFTING JETS DEGAS PUMP / AUX STM 21 AS p4M 7

5 7

(

21 HOUSE SERVICE BOILER I/S(/), SEC, O/S 22 21

,TATION AIR COMPRESSORS I/S(1), STBY, SEC, O/S 21 L//

21 INSTUENT AIR I/S (/,STBY, SEC, 0/S COMPRESSORS 22 7

DSR 1 REV. 91 UNIT 2 CENTRAL CONTROL ROOM LOG Page 16 of 17

END DATE Al ARM PANEL TEST ( + 31 )

'UI TS J_

TIME ALARM PANEL UNITS 1900 -0700 1 0700-1900

-~~ ~

~

-'I TA EDISON MONITOR FOR UNIT 1 RIVER WATER PUMPS

-11, UNIT 1 SUPERVISORY PANEL HP & LP TURBINE SOFT SIDE VIBRATION MONITOR (Bentley Nevada)

HP & LP TURBINE GENERATOR (Bentley Nevada )

21 & 22 MBFP VIBRATION MONITOR

( Bentley Nevada )

HP & LP TURBINE HARD SIDE VIBRATION

( Bentley Nevada ) ( Upper Panel )

HP & LP TURBINE HARD SIDE VIBRATION

( Bentley Nevada ) ( Lower Panel )

G.E. GENERATOR PANEL ACCIDENT ASSESSMENT PANEL 1 (AS-1 )

FLIGHT PANEL-UNIT 1 ( 1 FAF )

DIESEL FIRE PUMP AREA RADIATION MONITORS C- -

7-7-

7--

A 7-CONTAINMENT BUILDING FIRE PANEL (+ 32)

CENTRAL CONTROL ROOM FIRE ALARM PANEL PA-1 (* 26)

AUXILIARY BOILER FEED PUMP BUILDING FIRE PANEL (+ 32)

PAB BUILDING FIRE PANEL (+ 32)

M.O. BUILDING FIRE PANEL (* 32)

RCP VIBRATION MONITOR TURBINE FIRST OUT (FAF)

PRESSURIZER STEAM GENERATOR AND G.E. MAIN GENERATOR PANEL (FbF)

Alarm Panel Tested

(/)

REACTOR CONTROL PANEL ( FCF )

A_

A__

C> T I TK lIc REAUCO FNII uuI rMiNtL k rLr ) j PROCESS RADIATION MONITORS (SAF-1 )

REACTOR COOLANT SYSTEM (SAF)

J CCR SAFEGUARDS (SBF-1)

L CCR SAFEGUARDS (SBF-2)

CONDENSATE AND BOILER FEED (SCF)

TURBINE RECORDER (SDF)

L TURBINE AND G.E. GENERATOR START-UP (SEF)__

CHEMICAL AND VOLUME CONTROL (SFF) t AUXILIARY COOLANT SYSTEM ( SGF )

CCR ELECTRICAL ( SHF )

l

~~COOLING WATER AND AIR ( SJF )

f BEARING MONITOR ( SKF )C WELD CHANNEL (SLF)

CCR SAFETY INJECTION (SMF)

/

ELECTRIC HEAT TRACING AND DELUGE (SOF)(SO ji CCR SEQUENCE OF EVENTS REVIEWED ( + 34)

(___)____)

DSR 1 REV. 91 UNIT 2 CENTRAL CONTROL ROOM LOG Page 17 of 17

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility:

Task

Title:

K/A

Reference:

Indian Point Unit 2 Review (For Approval) A Completed Surveillance 2.2.12 (3.4)

Task No.:

JPM No.:

N/A 2003 NRC A2 SRO Examinee:

Facility Evaluator:

Method of testing:

Simulated Performance:

Classroom NRC Examiner:

Date:

X Simulator Actual Performance:

Plant X

READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

Task Standard:

Required Materials:

General

References:

Handouts:

Initiating Cue:

Time Critical Task:

Validation Time:

The Plant is at 100% power. All equipment in service.

PT-Q26A, 21 Service Water Pump Train Operational Test, was performed on your shift.

Deficiency identified and TS action PT-Q26A Rev 9 PT-Q26A Rev 9 Partially completed PT-Q26A Rev 9 You have been directed by the Shift Manager to perform calculations per section 7.4 and acceptance criteria review and approval per section 10.0 of PT-Q26A No 15 minutes NUREG 1021, Revision 8, Supplement 1

Appendix C Page 2 of 4 PERFORMANCE INFORMATION Form ES-C-1 (Denote Critical Steps with an asterisk)

Performance Step: I Standard:

Calculates total pump head Determines head is approximately 275 feet by adding discharge pressure in feet with calculated value of suction pressure in feet Comment:

Performance Step: 2 Standard:

Determines acceptance criteria for total head is not met Section 10.3; 300.5 - 355.4 is acceptable surveillance value.

Greater than 307 for alert range criteria Comment:

Performance Step: 3 Standard:

Determines action required Step 10.6 requires action for surveillance failure - 21 SWP o Notify SM o Initiate a CR Comment:

Performance Step: 4 Standard:

CUE:

Inform the candidate of the following; You are the CRS. Are there any additional concerns or requirements associated with the failed surveillance?

Determines additional action required Candidate determines that Essential Service Water header requires 3 pumps operable IAW TS 3.3.F. 1 Non-Essential Service Water header requires 2 pumps operable IAW TS 3.3.F.2 Comment:

Terminating Cue:

When the candidate has completed the acceptance criteria determination and Technical Specification impact, the evaluation for this JPM is complete NUREG 1021, Revision 8, Supplement I

Appendix C Page 3 of 4 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.:

IP2 2003 NRC A2 SRO Examinee's Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result:

SAT UNSAT Examiner's Signature:

Date:

NUREG 1021, Revision 8, Supplement 1

Appendix C Page 4 of 4 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

The Plant is at 100% power. All equipment in service.

PT-Q26A, 21 Service Water Pump Train Operational Test, was performed on your shift.

INITIATING CUE:

You have been directed by the Shift Manager to perform calculations per section 7.4 and acceptance criteria review and approval per section 10.0 of PT-Q26A NUREG 1021, Revision 8, Supplement 1

1Endergy.

PT-Q26A Revision 9 NUCLEAR NORTHEAST INDIAN POINT STATION 1 and 2 21 SERVICE WATER PUMP Prepared by:

Reviewer:

SNSC Review:

Approval:

Technical Reviewer:

Reviewer:

(

BIENNIAL REVIEW Reviewer / Date

-111-1.----

Temporary Procedure Changes:

Change No.__

/

Date_

PT-Q26A.r9.wpd

PT-Q26A Revision 9

-Entergy,,

NUCLEAR NORTHEAST INDIAN POINT STATION 1 and 2 21 SERVICE WATER PUMP TEST EQUIPMENT & MATERIALS I Discharge Pressure Test Gauge (0-300 psig)

IF-3o-34 I S//?

I Strainer Inlet Test Gauge (0-300 psig) f300 iII Strainer Outlet Test Gauge (0-300 psig) 3 0

0-6 Vibrometer OR Microlog Fl-5002 Fl-5002 IIr (ICPM-1579) zj14b1 Tethered Ruler N/A N/A I

IF necessary, equipment may be added to the Suggested Equipment table WHEN in the field.

PT *Q26A.r9.wpd Page 2 of 19

PT-Q26A Revision 9 21 SERVICE WATER PUMP 1.0 PURPOSE 1.1 To demonstrate the operability of 21 Service Water Pump in accordance with Technical Specification 4.2 [Test Results Table I].

1.2 To demonstrate that pump performance is not in the Alert Range in accordance with Technical Specification 4.2 [Test Results Table II].

1.3 To demonstrate the operability of Check Valve SWN-1 by cycling the check valve closed [SC-C] and partially cycling the valve open [PS] in accordance with Technical Specification 4.2 [Test Results Table ll].

2.0 GENERAL INFORMATION 2.1 This test may be performed regardless of plant operating status.

2.2 Test Instruments may be installed OR removed out of the sequence specified in the test AND in parallel with other preparation OR completion steps.

2.3 This test may be performed on less than the total number of components as per the Test Engineer.

2.4 Reference Drawings 9321-F-2722 and 9321-F-209762.

2.5 When setting flow with analog gauges it is possible that the needle will fluctuate slightly above and below the required flow. Center the flow to obtain an equal deflection above and below the required flow. The result is the required flow.

2.6 Service water header pressure or Zurn strainer differential pressure MAY alarm depending on system conditions.

2.7 IF a service pump control switch is placed in "Pullout", THEN the "Safeguards Equipment Locked Open" will alarm.

PT-Q26A.r9.wpd Page 3 of 19

PT-Q26A Revision 9 2.8 21 Service Water Pump testing is conducted to meet the requirements stated in the Purpose as part of the Inservice Testing (IST) Program for Pumps and Valves. The following are major factors in procedure development and use.

a. Pump testing is conducted in accordance with OM-6 (Operation and Maintenance of Nuclear Power Plants, Part 6, Inservice Testing of Pumps in Light-Water Reactor Power Plants). This test requires various instruments to be used.in the test. OM-6 requires a certain accuracy for instruments (+1-2% analog full scale for pressure, flow rate, speed and differential pressure; +1-5 % for vibration). The instruments shall be calibrated in accordance with the Owner's quality assurance program. This test ensures this calibration frequency requirement is met by having the test planner or performer check and record the calibration due dates prior to the test.

b. The full-scale range of each analog instrument shall be not greater than three times the reference value. Digital instruments shall be selected such that the reference value shall not exceed 70% of the calibrated range of the instrument.

The preceding two range requirements do not apply to vibration instruments.

c. For a pump in a system declared inoperable or not required to be operable, the test schedule need not be followed. Within three months prior to placing the system in an operable status, the pump shall be tested and the schedule resumed.

d. If the recorded values do not meet the Operability Criteria in Test Results Table I, the pump shall be declared inoperable until the cause of the deviation has been determined and the condition corrected. If the recorded values do not meet the Alert Range Criteria in Test Results Table II, the frequency of testing shall be doubled until the cause of the deviation is determined and the condition corrected.

If the test demonstrates that the pump is inoperable or in alert, the instruments involved may be recalibrated and the test rerun.

e. This test is designed to be able to meet both Surveillance and Post Maintenance Testing (PMT) requirements. PMT's may be required for routine servicing as stated in OM-6. This term includes performance of planned preventive maintenance (e.g.,

replacing or adjusting valves in reciprocating pumps changing oil, flushing the cooling system, adjusting packing, adding packing rings or mechanical seal maintenance or replacement).

f. Service Water pump specifics:

1. OM-6 Tables 3a and 3b provide range formulas for vibration and differential pressure for vertical line shaft pumps where pump speed is greater than 600 rpm.

2. The adjustment of Service Water pump packing does not require the establishment of new reference values as stated in TP-SQ-1 1.017.

PT-Q26A.r9.wpd Page 4 of 19

PT-Q26A Revision 9 21 SERVICE WATER PUMP 1.0 PURPOSE 1.1 To demonstrate the operability of 21 Service Water Pump in accordance with Technical Specification 4.2 [Test Results Table I].

1.2 To demonstrate that pump performance is not in the Alert Range in accordance with Technical Specification 4.2 [Test Results Table II].

1.3 To demonstrate the operability of Check Valve SWN-1 by cycling the check valve closed [SC-C] and partially cycling the valve open [PS] in accordance with Technical Specification 4.2 [Test Results Table l1l].

2.0 GENERAL INFORMATION 2.1 This test may be performed regardless of plant operating status.

2.2 Test Instruments may be installed OR removed out of the sequence specified in the test AND in parallel with other preparation OR completion steps.

2.3 This test may be performed on less than the total number of components as per the Test Engineer.

2.4 Reference Drawings 9321-F-2722 and 9321-F-209762.

2.5 When setting flow with analog gauges it is possible that the needle will fluctuate slightly above and below the required flow. Center the flow to obtain an equal deflection above and below the required flow. The result is the required flow.

2.6 Service water header pressure or Zurn strainer differential pressure MAY alarm depending on system conditions.

2.7 IF a service pump control switch is placed in "Pullout", THEN the "Safeguards Equipment Locked Open" will alarm.

PT-Q26A.r9.wpd Page 3 of 19

PT-Q26A Revision 9 2.8 21 Service Water Pump testing is conducted to meet the requirements stated in the C

Purpose as part of the Inservice Testing (IST) Program for Pumps and Valves. The following are major factors in procedure development and use.

a. Pump testing is conducted in accordance with OM-6 (Operation and Maintenance of Nuclear Power Plants, Part 6, Inservice Testing of Pumps in Light-Water Reactor Power Plants). This test requires various instruments to be used in the test. OM-6 requires a certain accuracy for instruments (+/- 2% analog full scale for pressure, flow rate, speed and differential pressure; +/- 5 % for vibration). The instruments shall be calibrated in accordance with the Owner's quality assurance program. This test ensures this calibration frequency requirement is met by having the test planner or performer check and record the calibration due dates prior to the test.

b. The full-scale range of each analog instrument shall be not greater than three times the reference value. Digital instruments shall be selected such that the reference value shall not exceed 70% of the calibrated range of the instrument. The preceding two range requirements do not apply to vibration instruments.

c. For a pump in a system declared inoperable or not required to be operable, the test schedule need not be followed. Within three months prior to placing the system in an operable status, the pump shall be tested and the schedule resumed.

d. If the recorded values do not meet the Operability Criteria in Test Results Table I, the pump shall be declared inoperable until the cause of the deviation has been C

determined and the condition corrected. If the recorded values do not meet the Alert Range Criteria in Test Results Table II, the frequency of testing shall be doubled until the cause of the deviation is determined and the condition corrected.

If the test demonstrates that the pump is inoperable or in alert, the instruments involved may be recalibrated and the test rerun.

e. This test is designed to be able to meet both Surveillance and Post Maintenance Testing (PMT) requirements. PMT's may be required for routine servicing as stated in OM-6. This term includes performance of planned preventive maintenance (e.g.,

replacing or adjusting valves in reciprocating pumps changing oil, flushing the cooling system, adjusting packing, adding packing rings or mechanical seal maintenance or replacement).

f. Service Water pump specifics:

1. OM-6 Tables 3a and 3b provide range formulas for vibration and differential pressure for vertical line shaft pumps where pump speed is greater than 600 rpm.

2. The adjustment of Service Water pump packing does not require the establishment of new reference values as stated in TP-SQ-1 1.017.

PT-Q26A.r9.wpd Page 4 of 19

PT-Q26A Revision 9 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Use ONLY Test Equipment calibrated in accordance with approved calibration procedures.

3.2 Ensure pump starting limitations are adhered to during testing.

3.3 Ensure at least ONE other pump on the header is operating for Check Valve testing.

3.4 The Service Water Intake Bay is a FME area that requires enhanced controls as per SAO-150, "FOREIGN MATERIAL EXCLUSION AND CONTROL." The Cognizant Supervisor shall conduct a pre-job brief regarding FME controls. As per SAO-1 50, WHEN personnel are entering enhanced control areas for equipment performance monitoring AND IF enhanced controls are NOT required by other work in progress, THEN enhanced controls may be relaxed.

3.5 The Service Water Intake Bay is a confined space. Follow applicable guidance.

4.0 PREREQUISITES None 5.0 PERMISSION TO COMMENCE 5.1 OBTAIN permission from the Shift Manager/Field Support Supervisor (SM/FSS) to commence the test. The SM/FSS shall sign below indicating that permission has been granted.

SM/FSS to`-) / A PRINT I4AME SIGNATUlkL r3.r DATE~

SM/FSS PRINT NAME SIGNATURE DATE 5.2 INFORM the Control Room Supervisor (CRS) that the test is going to be performed.

Request CRS to sign below indicating notification.

CRS

6) 6 so~7dr-(

PRINT NAME bE DATE CRS PRINT NAME SIGNATURE DATE 5.3 RECORD the date that the field work actually began.

DATE PT-Q26A.r9.wpd Page5 of 19

PT-Q26A Revision 9 6.0 INITIAL CONDITIONS 6.1 Required equipment has been obtained AND has been verified to be within calibration.

6.2 Enhanced area FME controls pre-job brief has been conducted.

Cognizant Supervisor 4&

nitials Date (Az-7.0 7.1 INSTRUCTIONS 21 SWP Test Setup:

NOTE Ensure at least ONE other pump on the header is operating for Check Valve testing.

REFER to Technical Specification 3.3.F for applicable action statement based on current plant conditions.

7.1.1 REQUEST CCR Operator to PLACE 21SWP in PULL-OUT.

7.1.2 RECORD time.

Pump in PULL-OUT:

____c___I 7.1.3 ENSURE valve SWN-2, 21SWP Outlet Stop is OPEN.

Initials cog'-,--

Initials Initials NOTE 21SWP pump shaft remaining stationary indicates Check Valve SWN-1 Cycle Closed (SC-C).

7.1.4 7.1.5 a.

b.

c.

VERIFY 21SWP pump shaft remains stationary.

INSTALL Discharge Pressure Test Gauge as follows:

CLOSE SWN-58, P1-1193 Root Stop.

REMOVE PI-1193 installed at SWN-58, P1-1193 Root Stop.

INSTALL 0-300 psig Discharge Pressure Test Gauge downstream of SWN-58, P1-1193 Root Stop.

Initials L--k--

Initials Initials (A-Initials klA-PT-Q26A.r9.wpd Page 6 of 19

PT-Q26A Revision 9 7.1.6 MEASURE from the center line of discharge pipe to water surface using a tethered ruler AND RECORD Tide Level for suction pressure to the nearest inch.

Level i?

Ft.

0 Inches Initials _

7.1.7 RECORD "As Found" positions AND PERFORM the following valve line-up:

VALVE DESCRIPTION AS FOUND TEST POSITI SWN-851-Xl FI-5002 Low Side Stop OPEN SWN-850-X1 FI-5002 High Side Stop o1 OPEN SWN-850-X3 FI-5002 Equalizing Stop OPEN SWN-851 FI-5002 Low Side Root Stop CLOSED SWN-850 FI-5002 High Side Root Stop

_______CLOSED SWN-501 26SWP Pump Test Header Inlet Lo ck Clt LOCKED CLOSED SWN-502 25SWP Test Header Stop

(

Co LOCKED CLOSED SWN-503 24SWP Test Hdr Inlet Stop CG C

LOCKED CLOSED SWN-504 23SWP Test Hdr Stop (acm C

LOCKED CLOSED SWN-505 22SWP Test Hdr Stop Lo

,i7 &7 LOCKED CLOSED SWN-507 Overboard Drain Stop C)j)L_

OPEN SWN-506 21SWP Test Hdr Inlet Stop A

m)

OPEN SWN-2 21SWP Outlet Stop Dl CLOSED SWN-600 21 SWP Strainer Blowdown Stop Chase CLOSED 7.2 21SWP Test:

7.2.1 ENSURE oil level in 2lSWP is satisfactory.

Initials L 7.2.2 IF oil level is UNSAT, THEN NOTIFY SM PRIOR to starting pump.

7.2.3 REQUEST CCR Operator START 21SWP.

Initials (-,

Initials 7.2.4 RECORD Start Time:

Pump Started:

Initials L.4---

PT-Q26A.r9.wpd Page 7 of 19

PT-Q26A Revision 9 7.2.5 PERFORM the following steps to provide indication to test gauge AND flow to FI-5002:

a. OPEN SWN-58, P1-1193 Root Stop.

b. OPEN SWN-851, FI-5002 Low Side Root Stop.

c. OPEN SWN-850, FI-5002 High Side Root Stop.

Initials Z Initials Initials /

CAUTION USE caution WHEN throttling SWN-850-X3 so as NOT to "Peg" the flowmeter high.

NOTE Set flow as near as possible to exactly 1500 GPM.

7.2.6 THROTTLE valves SWN-507, Overboard Drain Stop AND SWN-850-X3, FI-5002 Equalizing Stop simultaneously UNTIL 1500 +/- 30 GPM flow rate is obtained with SWN-850-X3 fully closed. Initials 7.2.7 IF 1500 +/- 30 GPM cannot be obtained WHEN SWN-507 is throttled, THEN leave SWN-507 throttled AND THROTTLE flow to 1500 +/- 30 GPM using SWN-506.

Initials '(4 7.2.8 VERIFY piping OR excessive packing leakage is NOT present.

Initials 4-'--

7.2.9 WHEN 21SWP has run for a MINIMUM of 5 minutes, THEN RECORD the following:

CODE DESCRIPTION INSTRUMENT VALUE 21SWPO 21SWP Discharge Pressure 0-300 psig Test Gauge

/1(

psig 21SWFLO 21SWP Flow FI-5002

/5,*

0 GPM Initials ZG._

PT-Q26A.r9.wpd Page8 of 19

PT-Q26A Revision 9 7.2.10 PERFORM the following to RECORD vibration data:

ENSURE vibration measurements are broad band (unfiltered).

SET vibrometer to measure velocity in inches per second (IPS).

RECORD readings to the second decimal place (hundreths).

IF vibration points are NOT physically marked on the pump AND motor, THEN INITIATE a Condition Report (CR).

21 SWP VIBRATION LOCATION Motor (MA)

(AV) l (AH)

Motor Stool (D)

Discharge (C)

Johnston Pump PT-Q26A.r9.wpd Page 9 of 19

PT-Q26A Revision 9 NOTE AH AND AV are on the upper motor bearing housing area. Figure 1 shows elevation.

AH is parallel to discharge.

MA shall NOT be measured on the motor top hat. MA shall be measured from the top of the motor.

TREND CODE VIB (IPS)

AV (Upper Motor Bearing)

(*)

d v

AH (Upper Motor Bearing)

(*)

I. (

MA (Motor Axial)

(*)

C (Pump Suction Flange Parallel Flow)

D(Pump Suction Flange Cross Flow)

0. 2-C

SECTION Xi ACCEPTANCE POINTS Initials 7.3 21 SWP Test Restoration:

7.3.1 INFORM CRS that the tested Service Water Pump is about to placed on the header.

Initials L-----/

7.3.2 OPEN Valve SWN-2, 21SWP Outlet Stop.

Initials L-4-A Verifier.~T 7.3.3 PERFORM the following restoration lineup OR ALIGN valves as per the CRS:

Valve Description Position Initials Verifier SWN-506 21SWP Test Hdr Inlet Stop LOCKED CLOSED L

SWN-850-X3 FI-5002 Equalizing Stop OPEN 6 /

SWN-850-Xl FI-5002 High Side Stop CLOSED SWN-851-Xl FI-5002 Low Side Stop CLOSED SWN-850 FI-5002 High Side Root Stop CLOSED L.

d-l SWN-851 FI-5002 Low Side Root Stop CLOSED

~

l SWN-600 21SWP Strainer Blowdown Stop OPEN l

SWN-507 Overboard Drain Stop OPEN PT-Q26A.r9.wpd Page 10 of 19

7.3 7.3 PT-Q26A Revision 9

.4 PERFORM the following steps to remove the test gauge:

a. CLOSE valve SWN-58, P1-1193 Root Stop.

Initials L.

b. REMOVE test gauge at SWN-58, PI-1193 Root Stop.

Initials

c. INSTALL P1-1193 at SWN-58, P1-1193 Root Stop.

Initials '~'~Verifier T

d. OPEN SWN-58, PI-1193 Root Stop.

Initials Verifier

.5 PERFORM the following steps to measure the Strainer DP:

a. CLOSE Valve SWN-623-X1, P1-5680 Root Stop.

Initials..(>7

b. REMOVE P1-5680.

InitialsI

c. INSTALL 0-300 psig test gauge.

Initials ~

d. OPEN Valve SWN-623-Xl, P1-5680 Root Stop to test gauge.

Initials ~

e. CLOSE Valve SWN-624-X1, P1-5679 Root Stop.

Initials L*

f. REMOVE PI-5679.

Initials

g. INSTALL 0-300 psig test gauge.

Initials

h. OPEN Valve SWN-624-X1, PI-5679 Root Stop to test gauge.

Initials

i. RECORD Strainer Inlet pressure from the test gauge at valve SWN-623-X1.

Inlet Pressure:

/0

- psig Initials

j. RECORD Strainer Outlet pressure from the test gauge at valve SWN-624-X1.

Outlet Pressure:

I° psig Initials PT-Q26A.r9.wpd Page 1 1 of 19

PT-Q26A Revision 9 NOTE Strainer DP > 0 psid indicates Check Valve SWN-1 Partial Cycle Open (PS).

k. CALCULATE the Strainer DP by subtracting the value in Step 7.3.5j from the value in Step 7.3.5i.

DP = ('54 psig psig

=

2 psid (Step 7.3.5i)

(Step 7.3.5j)

Initials C I. CLOSE Valve SWN-624-X1, PI-5679 Root Stop.

Initials

m. REMOVE test gauge.

Initials

n. INSTALL P1-5679.

Initials LA(H' Verifier _

o. OPEN Valve SWN-624-X1, P1-5679 Root Stop.

Initials Verifier _

p. CLOSE Valve SWN-623-X1, P1-5680 Root Stop.

Initials _

q. REMOVE test gauge Initials

(

r.

INSTALL Pl-5680.

Initials

" Verifier __

s. OPEN Valve SWN-623-X1, PI-5680 Root Stop.

Initials Verifier 7.3.6 NOTIFY CCR operator that 21SWP may be operated as directed bythe CRS.

Initials (

PT-Q26A.r9.wpd Page 12 of 19

PT-Q26A Revision 9 7.4 21 SWP Test DP Calculation 7.4.1 CALCULATE 21SWP suction pressure:

Tide Level (Step 7.1.6):

(A)

Feet (B) inches (B) inches x.083 =

(C)

+

(A) = __

Pitt Initials 7.4.2 CALCULATE 21SWP discharge pressure:

21 SWPO (Step 7.2.9)

Psig X 2.31 PO tt Initials 7.4.3 CALCULATE 21SWP DP:

POft

+ Pltt _

=

21DPft 7.4.4 TRANSFER information to the Test Results Section 10 as follows:

a. IF the test is stopped PRIOR TO recording ANY of the Operability Criteria in Section 10, THEN MARK Sections 10.3, 10.4, AND 10.5 Not Applicable AND RESTORE the system as per the SM OR CRS.

b. INDICATE in the Test Results whether this test was performed as surveillance OR PMT. IF test is performed for BOTH surveillance AND PMT requirements, THEN INDICATE PMT as the reason for test.

c. ENTER data in ALL Tables.

8.0 DATA (TABLES)

Initials Initials 8.1 None.

PT-Q26A.r9.wpd Page 13 of 19

PT-Q26A Revision 9

9.0 COMMENTS

4 PT-Q26A.r9.wpd Page 14 of 19

10.0 10.1 PT-Q26A Revision 9 TEST RESULTS The Test Results "Surveillance Acceptance Criteria" are valid WHEN the signatures of the Test Engineer AND Verifier appear below.

Test Engineer

/

Date Verifier

/

Date 10.2 Circle the appropriate reason for performing this test below.

PMT SURVEILLANCE 10.3 RECORD the As Found values AND CIRCLE the appropriate response in the table below.

TABLE I 21SWP OPERABILITY CRITERIA Step Parameter Test Val ues PMT Acceptance Surveillance Result Criteria Acceptance Criteria 7.2.10 Vibration Point AV

< 0.7

< 0.6 SAT UNSAT (IPS) 7.2.10 Vibration Point AH

< 0.7

< 0.6 SAT UNSAT

( IP S )

7.2.10 Vibration Point MA

< 0.7

< 0.7 SAT UNSAT

( IP S )

7.4.3 21SWP DPft

> 290

> 300.5 SAT UNSAT 3 5 5.4 10.4 RECORD the As Found values AND CIRCLE the appropriate response in the Alert Range Table below.

TABLE II 21SWP ALERT RANGE CRITERIA Step Parameter Test Values PMT Acceptance Surveillance Result Criteria Acceptance Criteria 7.2.10 Vibration Point AV

< 0.32

< 0.25 SAT UNSAT (IPS)

<03<0.5ST__

7.2.10 Vibration Point AH

< 0.32

< 0.25 SAT UNSAT (IPS )__

7.2.10 Vibration Point MA

< 0.32

< 0.32 SAT UNSAT (IPS)__

7.4.3 21SWP DPft Not Applicable to

> 307 SAT UNSAT PMT

_ _ _N

/ A _ ( i f p i n t )

PT-Q26A.r9.wpd Page 15 of 19

PT-Q26A Revision 9 10.5 CIRCLE the appropriate response in the Valve Criteria Table below.

TABLE III VALVE CRITERIA Step Valve Acceptance Criteria Result 7.1.4 SWN-1 Cycle Closed (SC-C)

SAT UNSAT

[Idle pump does not rotate]

7.3.5k SWN-1 Partial Cycle Open (PS)

SAT UNSAT

[Strainer DP > 0 psid]

10.6 IF ANY results above are UNSAT, immediately inform the SM of the UNSAT conditions.

Name of SM Informed Date 10.7 Inform the CRS that field work is complete:

CRS Initials Date 10.8 IF ANY other unsatisfactory results are obtained OR abnormal indications observed during this test, record ALL explanations AND corrective action initiated (including any Condition Report numbers) in the Comments Section.

10.9 All individuals involved in test performance should print their name and sign below.

Print Name/Signature Print Name/Signature Print Name/Signature Print Name/Signature 10.10 Forward procedure to the Cognizant Supervisor for review.

PT-Q26A.r9.wpd Page 16 of 19

PT-Q26A Revision 9 11.0 SUPERVISOR REVIEW 11.1 Ensure the test is complete AND the Test Results Section is completed accurately.

11.2 IF ANY error is found in the recorded data that changes a SAT response to an UNSAT response in the Test Results Section, notify the SM IMMEDIATELY.

11.3 Initiate a Condition Report for ANY Test Results in Section 10.0 that are UNSAT or any unexplained test anomalies.

Condition Report number:_

11.4 COMMENTS:

Supervisor Print Name Signature Date 11.5 Forward procedure to the SM for review.

PT-Q26A.r9.wpd Page 17 of 19

PT-Q26A Revision 9 12.0 SM REVIEW 12.1 IF ANY Test Results Response was UNSAT, verify that a Condition Report has been written to correct the outstanding deficiency.

12.2 Ensure ALL applicable actions are taken in accordance with Technical Specifications OR other applicable documents.

12.3 Verify that all comments in steps 9.0 and 11.4 were reviewed and dispositioned.

12.4 COMMENTS:

SM Print Name Signature Date 12.5 Forward procedure to Test and Performance for review.

PT-Q26A.r9.wpd Page 18 of 19

PT-Q26A Revision 9 13.0 TEST ENGINEER REVIEW 13.1 TEST ACCEPTANCE 13.1.1 Ensure required data AND initials are entered in the test.

13.1.2 Ensure the Test Results AND subsequent sections are completed.

13.1.3 Ensure ALL deficiencies AND abnormal conditions noted have adequate corrective action identified AND ANY applicable Condition Report numbers are noted.

13.1.4 IF ANY discrepancy is found during the test review, correct the discrepancy or initiate a Condition Report.

Condition Report number:_

13.2 COMMENTS:

13.3 ADDITIONAL TEST ENGINEER REQUIREMENTS 13.3.1 UPDATE valve trending computer program.

Test Engineer Print Name Signature Date PT-Q26A.r9.wpd Page 19 of 19

L'dergy A

r "N

vi~--flem PT-Q26A Revision 9 NUCLEAR NORTHEAST INDIAN POINT STATION 1 and 2 21 SERVICE WATER PUMP Prepared by:

Reviewer:

SNSC Review:

Technical Reviewer:

Reviewer:

(

Approval:

)~

,4 4s -

BIENNIAL REVIEW Reviewer / Date Reviewer / Date Temporary Procedure Changes:

Change No.

/

Date PT-Q26A.r9.wpd

7Entergy, PT-Q26A Revision 9 NUCLEAR NORTHEAST INDIAN POINT STATION 1 and 2 21 SERVICE WATER PUMP TEST EQUIPMENT & MATERIALS Discharge Pressure Test Gauge (0-300 psig) 4

-36 S-36 Strainer Inlet Test Gauge (0-300 psig)

IA

-6 5

3X /a3 Strainer Outlet Test Gauge (0-300 psig)

-30067

-6 Vibrometer OR Microlog it eK--3 4041/o3 FI-5002 FI-5002 (TCPM-1579)

N/A Tethered Ruler N/A N/A I

IF necessary, equipment may be added to the Suggested Equipment table WHEN in the field.

r PT-Q26A.r9.wpd Page 2 of 19