I

ATTACHMENT 9.2 ENGINEERING CALCULAT1ON COVER PAGE

Sheet 1 of 13

[-] ANO-1 El ANO-2 El GGNS El IP-2 E1 IP-3 El PLP

C] JAF SPNPS ElRBS El VY [I W3

El NP-GGNS-3 [I NP-RBS-3CALCULATION ()EC # 12609 (2) Page I of

COVER PAGE

(3) Design Basis Calc. [0 YES I-]NO 1(4) I•CALCULATION [ EC Markup

•)Calculation No: IN11-245 ( Revision: 2

(7) Title: Setpoint Calculation for PS-2390A & B, Condensate Tank -")Editorial:Low Level Transfer E]1 YES O•NO

I

(9) System(s): 23 (10) Review Org (Department): I & C Design

(11) Safety Class: (12) Component/Equipment/StructureType/Number: ___________

Z Safety / Quality Related Type/NPSber:PS 2390A PS 2390B

r- Augmented Quality Program

r- Non-Safety Related

(13) Document Type: CALC

(14) Keywords (Descriptionlropical

Codes):

REVIEWS

(15) Name/Sian ur/Dae (16) NameSignture.0"nat

0D. Richard Aai&Y---•4,z(-Responsible Engineer Design Verifier lupervisor/Approval

ReviewerComments Attached El Comments Attached

ATTACHMENT 9.3 CALCULATION REFERENCE SHEETATTACHMENT 9.3 CALCULATION REFERENCE SHEET

Sheet 2 of 13

CALCULATION CALCULATION NO: IN1-245REFERENCE SHEET REVISION: 2

I. EC Markups Incorporated N/A to NP calculations)II. Relationships: Sht Rev Input Output Impact Tracking

Doc Doc Y/N No.1. Calculation M-501 1 X 03 N2. FSAR X 0 N3. PNPS Tech Spec X X Y10. SM418 2 3 X X Y5.

III. CROSS REFERENCES:1. NRC Regulatory Guide 1.105, Rev. 32. ENN Engineering Guide ENN-IC-G-003, Rev. 03. ASME Steam Tables, 5th Edition4. ENN-MS-S-009-PNP, Rev. 05. PNPS Equipment Qualification Master List, Rev. 456. SUDDS/RF92-039, Rev. 07. IAS PS-2390A PARAMETERS8. IAS PS-2390B PARAMETERS9. G. E. Data Sheet 225A575010. Dwg. M209, Rev. 6611. Dwg. M243, Rev. 5112. Dwg. M244 sh. 1, Rev. E3013. Dwg. M184, Rev. E1414. Dwg. E153, Rev. 215. Dwg. M1J14-14 sh.1, Rev. 2616. Dwg. M1J14-14 sh. 2, Rev. E417. Dwg. M1J16-10, Rev. 2518. Dwg. M1J17-12, Rev. 2419. Dwg. M1J19-19, Rev. 1620. Dwg. M1J20-5, Rev. 1521. Dwg. C-338, Rev. 322. Dwg. SM418 sh.3, Rev. E223. ABB Impell Project Instruction No. 25-226-PI-001, Rev. 224. PNPS Procedure 8.M.2-2.5.6

IV. SOFTWARE USED:

Title: N/A Version/Release: Disk/CD No._

V. DISK/CDS INCLUDED:

Title: N/A Version/Release Disk/CD No.

VI. OTHER CHANGES: I

I

ATAHMENT 9.4 1 RECORD OF REVISION

SheeT 9 RECORD OF REVIsIO

Sheetslto Etrg3oretieAcin

eorfR-N-13-082

Revision 13epord of Reiifslon

This change is incorporating Engineering Change EC1I2609. The changesare a result of Entergy Corrective Action Report CR-PNP-2006-O1 802-

2 CA15.

4.

-U

4. TABLE OF CONTENTS

page1.0 Calculation Cover Page 12.0 Calculation Reference Sheet 23.0 Record of Revision 3

4.0 Table of Contents 45.0 Purpose 4

6.0 Conclusion 47.0 Input and Design Criteria 5

8.0 Assumptions 119.0 Method of Analysis 1110.0 Calculation 1111.0 Attachments 13

5. PURPOSE

The calculation provides the uncertainty analysis for the CST level switches PS-2390A andPS2390B. It determines the level setpoint of the switches which ensures automatic transfer ofthe HPCI suction from the CST to Suppression Pool before CST inventory is depleted.This revision to calculation IN1 -245 is incorporating a change to the CST low water levelSuppression Pool transfer setpoint analytical limit. Reference calculation M-501. The changeis being made to resolve concerns relating to vortexing in the CST resulting in air ingestion inthe suction of the HPCI pump. These concerns were identified in Entergy Corrective ActionReport CR-PNP-2006-01802-CA15.The calculation will support Nuclear Change EC1 2609 and will require FSAR and Tech Specrevision.

6. CONCLUSION

The calculation determined the following:

Trip Setpoint:58 inches from tank zero, or 8.6 psig (this includes hydrostatic head pressure correction for theelevation difference between the measured level of the tanks and the location of the pressureswitches; i.e. +6.5psig) see attachment 2.

Technical Specification Allowable Value:>-46 inches from tank zero, or >8.17 psig (this includes hydrostatic head pressure correctionfor the elevation difference between the measured level of the tanks and the location of thepressure switches; i.e. +6.5psig) see attachment 2.

Note, the setpoint Allowable Value listed in Technical Specification Table 3.2.B requiresrevision. The new value is > 46 inches above tank zero.

Setpoint Analytical Limit:43 inches from tank zero, or 8.05 (psig) (this includes hydrostatic head pressure correction forthe elevation difference between the measured level of the tanks and the location of thepressure switches; i.e. +6.5psig) see attachment 2.

Setpoint Reset Value:< 141 inches from tank zero, or "11.6 (psig) (this includes hydrostatic head pressurecorrection for the elevation difference between the measured level of the tanks and thelocation of the pressure switches; i.e. +6.5psig) see attachment 2 and note 4.

No Adiust Limit:8.4 to 8.8 psig

Surveillance Interval:Once per 3 months

M&TE Accuracy:±0.03 psig (Specified in section 5 of PNPS Procedure 8.M.2-2.5.6)

7. INPUT AND DESIGN CRITERIA

Section 7.4.3.2.5 of the FSAR describes the control scheme of the CST low level SuppressionPool transfer. It states three pump suction valves are provided in the High Pressure CoreInjection (HPCI) System. One valve lines up to the pump suction from the CST and the othertwo from Suppression Pool. The CST is the preferred source. Upon HPCI initiation if thesuction valve of the CST is closed, the initiation signal opens it. If the water level in the CSTfalls below the Suppression Pool transfer level setpoint, the Suppression Pool suction valvesopen automatically after a 3 second time delay. The time delay for the suppression poolsuction valve opening is introduced to prevent false (transient) signals from initiating suctiontransfer. When the suppression suction valves are fully open, the CST suction valveautomatically closes. Pressure switches PS-2390A and B are used to detect the CST lowwater level condition. Either switch can initiate opening of the Suppression Pool suctionvalves.

The CST suction valve does not actually receive a signal to close until after the 3 second timedelay plus the cycle time of the suppression pool suction valves to fully open. The delay isinsignificant with respect to the change in water level in the CST and is accounted for in thedetermination of the analytical limit.

i.e. CST Tank Level Change = (HPCI + RCIC Flow)(Time Delay)/(CST Surface Area)

Figure 7.1 - Condensate Storage Tank HPCI Pump Suction Low Level

References:Dwg. M-209, Dwg. M-243Dwg. M-244, Dwg. E-153

Dwg. M1J14-14 shl, Dwg. M1J16-10Dwg. M1J17-12, Dwg. M1P430-12

Calculation Input Data for the uncertainty/setpoint determination is provided in Table 7.1.

TABLE 7.1 - Loop Module Data Sheet

Title Descriptive value References RemarksComponent ID PS-2390A/B M209Service Description Provide signal to open

MO-2301-35 & MO-2301- FSAR 7.4.3.2.536 on low CST level

Location Reactor Bldg. Aux. Bay, SUDDS/RF #92-

East Wall 039 Attach. KEl. 8'- 12" Dwg. M184

Manufacturer IAS PS-2390A&B

Static-O-Ring ParametersModel Number IAS PS2390A&B

6N-AA2-X5PP ParametersQuality Category Q ENN-MS-S-009-

PNPAdjustable Range 2 - 25 psig GE Instrument See Note 11

(55.4 - 692 inches H20) Data Sheet225A5750

Process Calibrated Range N/A Setpointcalibration only

Input Signal Calibrated N/A SetpointRange calibration onlyOutput Signal Calibrated N/A SetpointRange calibration only

Reference Accuracy (RA) N/A See Note 8Drift (DR) ± 0.38 psig Attachment 1 See Note 8Static Pressure Effect (SP) N/A This error is

applicable toDP instruments

onlyExternal Pressurization N/A See Note 13Effect (EP)Overpressure Effect (OP) N/A See Note14Temperature Effect See Note 3Normal (TE) ± 0.175 psigAccident (ATE)Humidity Effect (HE) N/A See Note 15Radiation Effect (RE) N/A PNPS See Note 5

EnvironmentalQualificationMaster List

Seismic Effect (SE) ± 0.25 psig Attachment See Note 6

Insulation Resistance N/A See Note 7Effect(IR)Power Supply Effect (PS) N/A See Note 7Indicator Reading N/A No Indicator

Uncertainty (R)Process Measurement N/A See Note 16Effect (PM)Primary Element Accuracy N/A No Primary(PE) ElementMeasurement and Test N/A Procedure See Note 8Equipment Uncertainty 8.M.2-2.5.6(MTE)Technical Specification if _18 inches above tank zero Tech Spec Table See Note 2Applicable 3.2.BAnalytical Limit (AL) or 43 inches above tank zero Calculation M- See Note 10Nominal Process Limit 501(NPL)Allowable Value (AV) -46 inches above tank zeroSetPoint:

Trip (NTSP) 58 inches above tank zeroReset (RSV) <141 inches above tank See Note 4

zeroCalibration Frequency Once per 3 months Tech Spec Table

± 25% 4.2.B and section1; Definitions

As-Found Tolerance (AFT) ± 0.43 psig Section 10This calculation

As-Left Tolerance (ALT) ± 0.2 psig Procedure8.M.2-2.5.6

Calibration Procedure No. 8.M.2-2.5.6Module Algorithm N/AEQ and/or Functional N/A Equipment isOperating Environment non-EQSafety Function / Other See Note 1Functional requirementsFunction Duration N/A Note 5 The function

duration is notimportant

because theswitches are

non-EQNormal Operation Upper N/A DecreasingLimit (NUL) SetpointNormal Operation Lower 126 inches from tank zero See note 9Limit (NLL)Operating Margin (OM) 68 inches Section 10OpertinMarinOM)_F________ IThis calculation_

I

Notes

1. The safety function of the switches is to provide signal to initiate transfer of HPCI pumpsuction from the. CST to suction from the suppression pool upon CST low water levelcondition. These switches are listed as 'Q' in the 0-List.

2. Tech Specs Table 3.2.B specifies Condensate Storage Tank Low Level Trip Function must be>18" above tank zero, minimum of 2 operable Instrument Channels per Trip System. TechSpec Table 4.2.B specifies Calibration Frequency once/3 months.

3. Per Attachment 3; the Temperature Effect (TE) is 2% of Full Range (FR.) per 1000F. PerFSAR Table 10.9-1 and 10.9-2, maximum and minimum temperatures for the area theswitches are located are 1050F and 60°F respectively. The calibration temperature is assumedto be 700F. For conservatism, the larger AT is used to determine TE:

AT=105-70AT=35 0 F

AT 35TE--+ (2%of FR* -TTE--' (0.02 * 25, 10010010

TE---- 0. 175 psig

4. Empirical data from obtained from the PNPS calibration records (Reference PNPS Procedure8.M.2-2.5.6) show that PS2390A and PS2390B reset differential is within the G.E. InstrumentData Sheet Specifications for Reset Span Differential, 0.5 to 3 psid (see Reference 9). Addingthe upper limit of the pressure switch reset differential span to the plant setpoint confirms theswitch will not reset until after the CST level returns to a level greater than the NLL (NormalOperation Lower Limit). This will prevent opening the CST suction valve to HPCI/RCIC untilthis level is achieved.

5. Per the PNPS Equipment Qualification List, the pressure switches are not EQ qualified. Theswitches are not required to function for a harsh environment. Therefore, this calculation willbe performed for normal operating conditions only.

6. The switches are seismically qualified. Per the seismic qualification test results, (seeAttachment 3) the SOR switches function normally before and after seismic simulation. Thevendor specifies an accuracy of ± 1% Full Range. This value will be used in this calculationfor the seismic effect (SE).

7. The Insulation Resistance Effect and Power Supply Effect are applicable to low energy analogsignals and do not apply to ON/OFF mechanical devices. The switches PS-2390A&B areON/OFF mechanical devices that open and close 125V DC contacts. These errors are notapplicable to these devices.

Notes (cont.)

8. The sensor drift was statistically analyzed in Attachment 1 in accordance with ABB ImpellProject Instruction 25-226-PI-001. The analysis used the data obtained from empirical datafrom 11/6/87 through 8/22/2007 obtained from the PNPS as-found/as-left instrumentcalibration records (reference PNPS Procedure 8.M.2-2.5.6). The calibration frequency of theswitches for the above data is once per 3 months * 25%. The value obtained from thestatistical analysis has a probability and confidence of 95/95%.

From attachment 1, the drift value was determined to be ±0.38 psi

The sensor drift determined is considered to include the effects of measurement and testequipment (M&TE) and Reference Accuracy. Therefore, values will not be included in thiscalculation for M&TE Uncertainty or RA (Reference Accuracy).

9. The Condensate Storage Tanks provide the preferred supply to the HPCI and RCIC systems.The Torus water storage provides the back up emergency HPCI and RCIC system supply. Allsuctions for the CST are located 10.5 feet (126 inches from the bottom of the tank;approximately 75,000 gallons) above the HPCI and RCIC suctions. Two stand pipes are ineach tank, both are 10.5 feet high, one is for return water and the other is for the transferpump supply. This ensures that there is a reserve available for HPCI and RC1C. The bottompenetration is normally lined up to the HPCI and RCIC systems.

10.Analytical Limit calculated in M-501, Rev 1, Minimum CST Level for Transfer of HPCI PumpSuction to Torus.Analytical Limit, AL = 43 in; converted to psig (The density of water at 40 deg F is 62.426lbs/ft)

43in*62.4261bs Yft3

ALpig - 1728in3 /ft 3 1.553psig (rounded to 1.55 psig)

11. Pressure Switch Range is obtained from G.E. Instrument Data Sheet (Cross Reference 7),and as read from data plate on switches. Exact replacements can no longer be purchasedfrom SOR. Current model of similar equipment has a higher adjustable range, 3-30 psiginstead of 2-25 psig, see Attachment 5. Replacement of this switch with new equipment, ifneeded at some future date will require revision to this calculation.

12. CST overflow line at 39.5 ft. (474 inches from the bottom of the tank).

13. The External Pressurization Effect is not applicable because both sides of the pressure switchsensing mechanism are referenced to atmosphere. (i.e. Both the tank and switch are vented toatmosphere.) Therefore any change in the external or ambient pressure at the switch will becancelled by the change in pressure at the Condensate Storage Tank.

14. The Overpressure Effect is not applicable because the Condensate Storage Tank is40 feet high and vented. The maximum pressure of the process is within the calibration rangeof PS-2390A & B. Therefore, it is not possible to overpressure PS-2390A & B.

Notes (cont.)I

15. The housing of the pressure switch is NEMA 4 weather tight. Pressure switches are notnormally affected by humidity and the manufacture does not specify an error due to humidityvariation. Therefore, the humidity effect is considered to be insignificant, HE = 0 psig.

16. The Process Measurement Effect is due to process temperature changes and piping frictionlosses. Neither of these effects results in a non-conservative error. The first effect is notapplicable because the setpoint determination is performed assuming the processtemperature (including instrument line fluid) is at 40 degrees F. The temperature of the CSTwater is controlled at greater than 45 OF. See drawing SM418 sh. 2 for temperature control ofthe CST. Conversion of the CST level in inches of water to pressure in lbs/in2 is calculated at400F. The density of water at 40 degrees F is 62.426 lbs/ft3 . The conversion of the setpointelevation to sensed pressure at PS2390A & B location is performed assuming the lowesttemperature of the Condensate Storage Tank range of operability. This is a conservativemethod of analysis which results in a pressure switch measurement that corresponds to aCST level that is lower than actual. Also, fluid flowing through a piping system experiences adrop in pressure due to piping friction. The loss of process pressure due to piping frictionresults in a lower pressure at the location of the pressure switch which is located in theHPCI/RCIC suction piping. Reference drawing M209. This error is not applicable because itcauses the pressure switch to trip at a higher CST level than required which is conservative.

8. ASSUMPTIONS

CST temperature is assumed to be at the lowest value of the operating range. Refer toDrawing SM418 sh. 3. This is a conservative assumption which will result in an acceptablesetpoint for all operating temperatures of the CST.

9. METHOD OF ANALYSIS

This calculation is performed based on the methodology described in ENN-IC-G-003"Instrument Loop Accuracy and Setpoint Calculation Methodology" and uses ABB ImpellProject Instruction No. 25-226-PI-001 for analysis of the as-found and as-left instrumentcalibration data. The calculation has been prepared in accordance with EN-DC-126"Engineering Calculation Process".

10. CALCULATION

The setpoint for the CST low level Suppression Pool transfer is determined in accordance withrigor and equations prescribed in ENN-IC-G-003. The rigor as identified in ENN-IC-G-003 istype 1. The applicable equations used in the analysis follow.

Instrument Module Uncertainty, en

The general form of the module uncertainty equations are:

en+ = +(RA2+DR 2+TE2+HE2+RE 2+pS2+Sp 2+op2+S E2+Ep 2+ALT 2+MTE 2+R2)112 +B

e, = -(RA 2+DR 2+TE2+HE 2+RE 2+pS2+Sp 2+op 2+S E2+EP 2+ALT 2+MTE 2+R2)/2 -B

Channel Uncertainty, CU

The general form of the channel uncertainty equation are:

CU+ =+(pM2+PE2+e12+.. .+e2)112 +8

CU- =-(pM2+PE 2+e12+. ..+e2)1/2 -B

Trip Setpoint. NTSP

The general form of the trip setpoint equation is:

NTSP = AL±(CU+Margin)

As-Found Tolerance, AFT

The general form of the As-Left Tolerance equation is:

AFTn = (RAn2+DRn2+ALTn2)1l 2

Allowable Value, AV

The general form of the Allowable Value equation is:

AV = NTSP+(AVTSM+Margin)

AVSTM = AFT

Operatina Margin, OM

The general form of the Operating Margin equation is:

OM = NLL - NTSP

From the data in Table 7.1 the setpoint, Allowable Value and operating margin are determinedusing the above equations. Note, because the setpoint is decreasing, there are no biases andthere is only one component in the loop being analyzed the following equations are applicable.

Switch Error

eswitch+ =+(DR 2+TE2+SE2+ALT 2)112 +B

=+(0.382+0. 175 2+0.25 2+0.2 2)1/2

=+0.53 psig

Loop Error

CU+ =+(0.e sigh2)1/2

=+0.53 psig

Trip Setpoint

NTSP = AL±(CU+Margin)

= 1.55+(0.53+ 0)

= 2.08 psig, or 2.1 psig (The actual plant setting is obtained by adding the head

correction from Attachment 2. The plant setpoint is 8.6 psig)

The Trip Setpoint is converted to inches from the bottom of the tank as follows:

(2.1 psig) (27.73 inWC / psi @ 68 degree F) = 58.2 inches, say 58 inches

The As-Found Tolerance and Allowable Value are:

As-Found Tolerance

AFTswftch = (DRswch 2 +ALTswkch 2 )1 2

= (0.382+0.22)1/2

= ±0.43 psig, or (0.43psig) (27.73 inWC / psi @ 68 degree F) = ±11.9 inches

Allowable Value

AV = NTSP-(AVTSM+Margin)

= 2.1 -(0.43 + 0)

= 1.67 psig (Adding the head correction from Attachment 2, the AV is 8.17 psig)

The Allowable Value is converted to inches from the bottom of the tank as follows:

(1.67 psig) (27.73 inWC / psi @ 68 degree F) = 46.3 inches, say 46 inches

Operatina Margin

The Operating Margin in inches is:

OM = NLL- NTSP

= (126 - 58) inches

= 68 inches

11. ATTACHMENTS

1. PS-2390NB Drift Data Analysis (6 pages)2. PS-2390A & B Instrument Leg Head Correction (1 page)3. Memo dated 10/19/1987 from Virginia Woldow to John Torbeck (1 page)4. Boston Edison Notes of Telecon - dated 1/11/1999 (1 page)

ATTACHMENT 1PS-2390A/B DRIFT DATA ANALYSIS

CALC. NO. IN1-245

DATE DATA STATUS CAL DATA INTERVAL REMARKS DRIFT DATA 1ST OUTLIER 2ND OUTLIERPS-2390B

6/2/1994 AS FOUND 7.70AS LEFT 7.70

9/6/1994 AS FOUND 7.70 96 0.00 0.00 0.00AS LEFT 7.70

12/12/1994 AS FOUND 7.70 97 0.00 0.00 0.00AS LEFT 7.70

3/14/1995 AS FOUND 7.70 92 0.00 0.00 0.00AS LEFT 7.70

6/28/1995 AS FOUND 7.82 106 0.12 0.12 0.12AS LEFT 7.82

9/29/1995 AS FOUND 7.65 93 -0.17 -0.17 -0.17AS LEFT 7.65

1/3/1996 AS FOUND 7.89 96 0.24 0.24 0.24AS LEFT 7.89,

4/3/1996 AS FOUND 7.90 91 0.01 0.01 0.01AS LEFT 7.90

7/1/1996 AS FOUND 7.84 89 -0.06 -0.06 -0.06AS LEFT 7.84

10/22/1996 AS FOUND 7.75 113 -0.09 -0.09 -0.09AS LEFT 7.751

12/27/1996 AS FOUND 7.93 66 0.18 0.18 0.18AS LEFT 7.93

4/7/1997 AS FOUND 7.85 101 -0.08 -0.08 -0.08AS LEFT 7.85

7/14/1997 AS FOUND 7.75 98 -0.10 -0.10 -0.10AS LEFT 7.75

10/16/1997 AS FOUND 7.83 94 0.08 0.08 0.08AS LEFT 7.83

1/20/1998 AS FOUND 7.80 96 -0.03 -0.03 -0.03AS LEFT 7.80

4/29/1998 AS FOUND 7.94 99 0.14 0.14 0.14AS LEFT 7.94 _

7/29/1998 AS FOUND 7.89 91 -0.05 -0.05 -0.05AS LEFT 7.89 _

10/19/1998 AS FOUND 8.00 82 0.11 0.11 0.11AS LEFT 8.00

1/1311999 AS FOUND 8.20 86 0.20 0.20 0.20AS LEFT 7.70

3/2/1999 AS FOUND 7.70 48 0.00 0.00 0.00

IN1_245.XLS Page I

ATTACHMENT 1PS-2390A/B DRIFT DATA ANALYSIS

CALC. NO. IN -245

AS LEFT 7.704/9/1999 AS FOUND 7.60 38 -0.10 -0.10 -0.10

AS LEFT 7.606/27/1999 AS FOUND 7.71 79 0.11 0.11 0.11

AS LEFT 7.719/1/1999 AS FOUND 7.70 66 -0.01 -0.01 -0.01

_AS LEFT 7.7011/18/1999 AS FOUND 7.60 78 0.10 0.10 0.10

AS LEFT 7.802/24/2000 AS FOUND 7.71 98 -0.09 -0.09 -0.09

AS LEFT 7.716/2/2000 AS FOUND 7.71 99 0.00 0.00 0.00

AS LEFT 7.718/30/2000 AS FOUND 7.79 89 0.08 0.08 0.08

AS LEFT 7.7912/11/2000 AS FOUND 7.50 93 -0.29 -0.29 -0.29

AS LEFT 7.822/28/2001 AS FOUND 7.76 89 -0.06 -0.06 -0.06

AS LEFT 7.86.5/29/2001 AS FOUND 7.70 90 -0.16 -0.16 -0.1-6

AS LEFT 7.708/28/2001 AS FOUND 7.65 91 -0.05 -0.05 -0.05

AS LEFT 7.6511/30/2001 AS FOUND 7.70 94 0.05 0.05 0.05

AS LEFT 7.7012/25/2002 AS FOUND 8.00 87 0.30 0.30 0.30

AS LEFT 8.005/28/2002 AS FOUND 7.88 92 -0.12 -0.12 -0.12

AS LEFT 7.888/26/2002 AS FOUND 7.97 90 0.09 0.09 0.09

AS LEFT 7.9711/26/2002 AS FOUND 7.71 92 -0.26 -0.26 -0.26

AS LEFT 7.7112/24/2003 AS FOUND 7.70 90 -0.01 -0.01 -0.01

AS LEFT 7.7015/27/2003 AS FOUND 7.60 92 -0.10 -0.10 -0.10

AS LEFT 7.60 _

8/26/2003 AS FOUND 7.60 91 0.00 0.00 0.00

AS LEFT 7.6011/24/2003 AS FOUND 7.76 90 0.16 0.16 0.16

AS LEFT 7.763/1/2004 AS FOUND 7.40 98 -0.36 .-0.36 -0.36

IN1_245.XLS Page 2

ATTACHMENT 1PS-2390A/B DRIFT DATA ANALYSIS

CALC. NO. IN1-245

AS LEFT 7.7065/2712004 AS FOUND 7.90 87 0.20 0.20 0.20

AS LEFT 7.90-8/23/2004 AS FOUND 8.30 88 0.40 0.40 0.40

AS LEFT 7.7611/23/2004 AS FOUND 7.60 92 -0.16 -0.16 -0.16

AS LEFT 7.6012/29/2004 AS FOUND 8.00 36 0.40 0.40 0.4O

AS LEFT 8.00-223/2005 AS FOUND 7.96 56 -0.04 -0.04 -0.04

AS LEFT 7.965/24/2005 AS FOUND 7.90 90 -0.06 -0.06 -0.06

AS LEFT 7.908/23/2005 AS FOUND 7.85 91 -0.05 -0.05 -0.05

AS LEFT 7.8511/21/2005 AS FOUND 8.20 90 0.35 0.35 0.35

AS LEFT 7.84P2/2/2006 AS FOUND 7.78 93 -0.06 -0.06 -0.06

AS LEFT 7.785/23/2006 AS FOUND 7.60 90 -0.18 -0.18 -0.18

AS LEFT 7.60 - _

8/22/2006 AS FOUND 7.70 91 0.10 0.10 0.10AS LEFT 7.70

1i/22/2006 AS FOUND 7.30 92 -0.40 -0.40 -0.40AS LEFT 7.80

2(23/2007 AS FOUND 7.90 93 0.10 0.10 0.10AS LEFT 7.90

5/23/2007 AS FOUND 7.98 89 0.08 0.08 0.08AS LEFT 7.98

8/22/2007 AS FOUND 7.90 91 -0.08 -0.08 -0.087.90

PS-2390A

6/2/1994 AS FOUND 7.70AS LEFT 7.70

9/6/1994 AS FOUND 7.60 96 -0.10 -0.10 -0.10AS LEFT 7.60

12/24/1994 AS FOUND 7.80 109 0.20 0.20 0.20AS LEFT 7.80,

-314/1995 AS FOUND 7.80 80 0.00 0.00 0.00AS LEFT 7.80

6/25/1995 AS FOUND 7.40 103 -0.40, -0.40 -0.40

IN1_245.XLS Page 3

ATTACHMENT 1PS-2390A/B DRIFT DATA ANALYSIS

CALC. NO. IN1-245

AS LEFT 7.759/29/1995 AS FOUND 7.62 96 -0.13 -0.13 -0.13

AS LEFT 7.621/3/1996 AS FOUND 7.97 96 0.35 0.35 0.35

AS LEFT 7.974/3/1996 AS FOUND 8.00 91 0.03 0.03i 0.03

AS LEFT 8.0017/1/1996 AS FOUND 7.94 89 -0.06 -0.06 -0.06

AS LEFT 7.9410/22/1996 AS FOUND 7.85 113 -0.09 -0.09 -0.09

AS LEFT 7.8512/27/1996 AS FOUND 7.97 66 0.12 0.12 0.12

AS LEFT 7.974/7/1997 AS FOUND 7.90 101 -0.07 -0.07 -0.07

AS LEFT 7.9017/14/1997 AS FOUND 7.85 98 -0.05 -0.05 -0.05

AS LEFT 7.8510/16/1997 AS FOUND 7.85 94 0.00 0.00 0.00

AS LEFT 7.851/20/1998 AS FOUND 7.90 96 0.05 0.05 0.05

AS LEFT 7.904/29/1998 AS FOUND 7.88 99 -0.02 -0.02 -0.02

AS LEFT 7.887/29/1998 AS FOUND 7.85 91 -0.03 -0.03 -0.03

AS LEFT 7.8510/19/1998 AS FOUND 7.90 82 0.05 0.05 0.05

AS LEFT 7.9011/13/1999 AS FOUND 8.00 86 0.10 0.10 0.10

AS LEFT 8.003/2/1999 AS FOUND 8.00 48 0.00 0.00 0.00

AS LEFT 8.004/9/1999 AS FOUND 8.00 38 0.00 0.00 0.00

_AS LEFT 8.0016/27/1999 AS FOUND 7.75 79 -0.25 -0.25 -0.25

AS LEFT 7.7519/1/1999 AS FOUND 7.92 66 0.17 0.17 0.17

_ AS LEFT 7.9211/18/1999 AS FOUND 8.00 78 0.08 0.08 0.08

AS LEFT 8.002/24/2000 AS FOUND 8.01 98 0.01 0.01 0.01

I AS LEFT 7.65

6/2/2000 AS FOUND 7.66 99 .0.01 0.01 0.01

INi_245.XLS Page 4

ATTACHMENT 1PS-2390A/B DRIFT DATA ANALYSIS

CALC. NO. IN1-245

AS LEFT 7.668/30/2000 AS FOUND 7.81 89 0.15 0.15 0.15

AS LEFT 7.8112/1/2000 AS FOUND 7.40 93 -0.41 -0.41 -0.41

AS LEFT 7.872/28/2001 AS FOUND 7.78 89 -0.09 -0.09 -0.09

AS LEFT 7.785/29/2001 AS FOUND 7.61 90 -0.17 -0.17 -0.17

AS LEFT 7.618/28/2001 AS FOUND 7.79 91 0.18 0.18 0.18

AS LEFT 7.7911/30/2001 AS FOUND 7.70 94 -0.09 -0.09 -0.09

AS LEFT 7.702/25/2002 AS FOUND 7.90 87 0.20 0.20 0.20

AS LEFT 7.905/28/2002 AS FOUND 7.90 92 0.00 0.00 0.00

AS LEFT 7.908/26/2002 AS FOUND 7.85 90 -0.05 -0.05 -0.05

AS LEFT 7.8511/26/2002 AS FOUND 7.77 92 -0.08 -0.08 -0.08

AS LEFT 7.772/24/2003 AS FOUND 8.00 90 0.23 0.23 0.23

_AS LEFT 8.005/27/2003 AS FOUND 7.60 92 -0.40 -0.40 -0.40

AS LEFT 7.608/26/2003 AS FOUND 7.80 91 0.20 0.20 0.20

AS LEFT 7.8011/24/2003 AS FOUND 7.92 90 0.12 0.12 0.12

AS LEFT 7.9213/1/2004 AS FOUND 7.90 98 -0.02 -0.02 -0.02

AS LEFT 7.905/27/2004 AS FOUND 7.64 87 -0.26 -0,26 -0.26

AS LEFT 7.648/23/2004 AS FOUND 7.60 88 -0.04 -0.04 -0.04

AS LEFT 7.6011/23/2004 AS FOUND 7.80 92 0.20 0.20 0.20

AS LEFT 7.8012/29/2004 AS FOUND 7.75 36 -0.05 -0.05 -0.05

AS LEFT 7.752/23/2005 AS FOUND 7.65 56 -0.10 -0.10 -04.10

AS LEFT 7.655/24/2005 AS FOUND 7.83 g 90 0.18 0.18 1 0.18

IN1-245.XLS Page 5

ATTACHMENT 1PS-2390A/B DRIFT DATA ANALYSIS

CALC. NO. IN1-245

A S L E F T 7 .8 3 -0 .5 38/23/2005 AS FOUND 7.30 91 -0.53 -0.53 -0.53

AS LEFT 7.7011/21/2005 AS FOUND 7.78 90 0.08 0.08 - 0.08

AS LEFT 7.782/22/2006 AS FOUND 7.75 93 -0.03 -0.03 -0.03

AS LEFT 7.755/23/2006 AS FOUND 7.90 90 0.15 0.15 0.15

AS LEFT 7.908/22/2006 AS FOUND 7.60 91 -0.30 -0.30 -0.30

AS LEFT 7.60 _

11/22/2006 AS FOUND 7.65 92 0.05 0.05 0.05AS LEFT 7.65 i

2/23/2007 AS FOUND 7.80 93 0.15 0.15 0.15AS LEFT 7.80

5/23/2007 AS FOUND 7.70 89 -0.10 -0.10 -0.10AS LEFT 7.70

8/22/2007 7.71 91 0.01 0.01 0.017.71,

AVERAGE 0.00 0.00 0.00__STANDARD DEVIATION 0.17 0.17 0.17

,COUNT 110 110 1101% OF ORIGINAL DATA POINTS 100.00% 100.00%195-/o/95% TOL. INT. PSI 0.38 0.38

INI_245.XLS Page 6

Attachment 2PS-2390A & B Instrument Leg Head Correction

Calculation Number IN1 -245

This attachment shows the method of solution, equations, values, tables and references used todetermine "water head correction" for PS-2390A/B.

Method of Solution

HP = EL * SG

HP = hydrostatic head pressureEL = elevation differenceSG = specific gravity of fluid

EL (elevation bottom of T1 05A and T1 05B) - (elevation midpoint of PS2390A and PS2390B)

Assumptions

Elevations from drawings used are assumed to be within ±1"; calculations will round off towardsthe conservative value.

Calculation

elevation T1 05A/B = 23ft Reference dwg. C338 Miscellaneous StructuresCondensate Tank Detailselevation PS2390A/B = 8.04ft Reference Attachment "K" SUDDS/RF#92-039 and verifiedby walkdown 12/17/98

EL = 14.96 ft elevation difference

SG = specific gravity of CST water at 40°F (minimum water temperature will create largest headcorrection)

SG = 62.426 lbs/ft3 Reference ASME Steam Tables

HP = (14.96ft)(62.4261bs/ft 3)HP = 933.891bs/ft2

or 6.48 psi, conservatively rounded to 6.5 psiq in PNPS 8.M.2-2.5.6

References

* C-338, Rev. El, Miscellaneous Structures Condensate Tank Details* SUDDS/RF92-039, Rev. 0, Setpoint Calc for PS2390A,B from Bechtel Corporation* ASME Steam Tables, 5th Edition

"f.•A'" " 1• j'ev. 2

1A1//.1 -24 5-CC I. L. lisher

October 19, 2987

02r John Torbeck

SUJ1C Seisuic and Ocher tests applcalbe to MIDt 209W12771003

The StAtic-0-3ing pressure witch, MO1 209A5127PO02, we@ asesmmiely toggedand found to operate normally iaU ". " ats as up to U $S,. /

The accuracy of the devike I :t IX of fua rangel the tauporature offect Is' 22 per 100'?. Teeting of the prlisure witich wea perform•ed at abtent temperatuze,

15601 and 2120r. (Normal temperature was considered to bo 70"1; 1.546 Ls theZ uam% m uge sed tebperature.)

o The pressure switches are quulified based on XZli Standards 323-1971 and 346-1971.

Tlst Results and qu•GlGficIaon data ato located Is DuI44P ecord f1l. (Don)ADO-10-4, Index 37.

Material SerVIce. elifteerLuI

C

iV

4rMc 1.Ar 4 /M1I2456

ABoston Edisonz roov coMePNY

NOTES OF TELECON

To: Joel Bradley. SOR. Inc. 1913) 881-0767

From: Joseph Tedeschi. BECOIDE&S. (Sa) 830-.830S

Dale: January 11, 1999(15:001 andJamiaryl 11, 1999(09:15)

Subject. Range of SOR Press, Switches. DECO I0 Nos. PS.2390A. 0

JoG Tede:hh called Mr. Bradley to obtain additional info. on iteadjustabl range of pressureSwltches PS-2390A & 6. SOR model no. SN-AA2-XSPP. The adjustable range specified lot theswitches in BECO setpaint cat:. E-634.3. Rev. I (SUDDS #92-039) contas references toconflicting ranges at 2 - 25 psig (body of cale.). and 2 - 30 psig (VlSI Spec. shis in Attach. "HI.A third n=-ft-ng saoure of informaton. the currant SOR catalog .identaies that the adjustablerange of the switches should be 7 - 30 psig based on the 8 -2 piston - spring combinationidentified in tho model no.

Mr. Bradley identified that the adjustable range of these switches has changed over the years forthe 6 - 2 Piston. spring combination and that in 1908. lia adjustable range for this type of switchwould have been 2 - 25 psig as specified in the body of the referenced BECO caltc. This in Iheappromxmate vintage of the switches installed at PNPSI.

Mr. Bradley also identified the make-up of the switch model no. as follows:

-. SN.•- X _

Piston Type \ Supplied with paper 10 Tag5 "Speciar requirements apply

Housing: Spring type 2Weather tight,314" RH NPT Elec. Conn.,Similar to current type NO but DPOT swiCthhas aluminum housing

Details on the 5 -speciar requirements, can probably be obtained i the SOR Nuclear Group werecontacted and provided with the specific equipment seral nroe.

C: B. Rancourt - OEM Group

M01

ATTACHMENT 9.1 DESIGN VERIFICATION COVER PAGE

Sheet I of 1DESIGN VERIFICATION COVER PAGE

Q ANO-1 El ANO-2 E IP-2 El IP-3 [I JAF E] PLP[]PNPS 0 VY Q GGNS E-RBS E] W3 ENP

Document No. IN 1-245 Revision No. Page 1 of 522

Title: Setpoint Calculation for PS-2390A & B Condensate Tank Low Level Transfer

[a Quality Related [] Augmented Quality Related

DV Method: Z Design Review El Alternate Calculation El Qualification Testing

VERIFICATION REQUIRED DISCIPLINE VERIFICATION COMPLETE ANDCOMM6ENTS RESOLVED (DV print, sign,

and date)

i- Electrical

El Mechanical

Instrument and A-K Barrie /9-25-09Control

Li Civil/Structural

r-I Nuclear

Originator: b. .vPrint/Sign/Date After Comments Have Been Aesolved

EN-DC-134, Rev. 2

ATTACHMENT 9.6 DESIGN VERIFICA71ON CHECKLISTATTACHMENT 9.6 DESIGN VERIFICATiON CHECKLIST

Sheet I of 3

IDENTIFICATION: DISCIPLINE:

Document Title: Setpoint Calculation for PS-2390A & B Condensate Tank Low Level Transfer -'CivillStructural'lElectrical

Doc. No.: IN 1-245 Rev. 2 QA Cat. IMhacal

A-K Barrie 9-25-09 ENuclearVerifier: Print S Date 0Other

Manager authorization forsupervisor performingVerification.

C3 N/A

Print Sign Date

METHOD OF VERIFICATION:

Design Review EL Alternate Calculations 0 Qualification Test Q3

The following basic questions are addressed as applicable, during the performance of any designverification. [ANSI N45.2.11 - 1974] [NP] [QAPD, Part 11, Section 3][NQA-1-1994, Part 11, BR 3,Supplement 3s- 1I].

NOTE The reviewer can use the "Comments/Continuation sheet" at the end for entering anycomment/resolution along with the appropriate question number. Additional items with newquestion numbers can also be entered.

1. Design Inputs - Were the inputs correctly selected and incorporated into the design?

(Design inputs include design bases, plant operational conditions, performancerequirements, regulatory requirements and commitments, codes, standards, field data, etc.All information used as design inputs should have been reviewed and approved by theresponsible design organization, as applicable.All inputs need to be retrievable or excerpts of documents used should be attached.See site specific design input procedures for guidance in identifying inputs.)Yes 0 No [3 N/A 13

2. Assumptions - Are assumptions necessary to perform the design activity adequately described andreasonable? Where necessary, are assumptions identified for subsequent re-verification when the detailedactivities are completed? Are the latest applicable revisions of design documents utilized?Yes 0 No [] N/A []

3. Quality Assurance - Are the appropriate quality and quality assurance requirements specified?Yes 0 No 1 N/A [I

EN-DC-134, Rev. 2

ATTACHMENT 9.6 DESIGN VERIFICATION CHECKLIST

Sheet 2 of 3

4. Codes, Standards and Regulatory Requirements - Are the applicable codes, standards and regulatoryrequirements, including issue and addenda properly identified and are their requirements for design met?Yes 0 No [ N/A []

5. Construction and Operating Experience - Have applicable construction and operating experiencebeen considered?Yes0• No [ N/A [I

6. Interfaces - Have the design interface requirements been satisfied and documented?Yes 0 No [I N/A 1]

7. Methods - Was an appropriate design or analytical (for calculations) method used?Yes 0 No [ N/A El

8. Design Outputs - Is the output reasonable compared to the inputs?Yes 0 No [I N/A []

9. Parts, Equipment and Processes - Are the specified parts, equipment, and processes suitable forthe required application?Yes 0 No 0 N/A 0l

10. Materials Compatibility - Are the specified materials compatible with each other and the designenvironmental conditions to which the material will be exposed?Yes I No 0 N/A 0

11. Maintenance requirements - Have adequate maintenance features and requirements beenspecified?Yes [ No [ N/A 0

12. Accessibility for Maintenance - Are accessibility and other design provisions adequate forperformance of needed maintenance and repair?Yes [ No [ N/A 0

13. Accessibility for In-service Inspection - Has adequate accessibility been provided to perform thein-service inspection expected to be required during the plant life?Yes [ No 0 N/A 0

14. Radiation Exposure - Has the design properly considered radiation exposure to the public andplant personnel?Yes 0 No 0 N/A [3

15. Acceptance Criteria - Are the acceptance criteria incorporated in the design documents sufficientto allow verification that design requirements have been satisfactorily accomplished?Yes 0 No [ N/A [E

16. Test Requirements - Have adequate pre-operational and subsequent periodic test requirementsbeen appropriately specified?Yes 0 No 0 N/A 0l

EN-DC-134, Rev. 2

ATrTACHMENT 9.6 DESIGN VERIFICATION CHECKLIST

Sheet 3 of 3

17. Handling, Storage, Cleaning and Shipping - Are adequate handling, storage, cleaning andshipping requirements specified?Yes 0 No 0 N/A 0

18. Identification Requirements - Are adequate identification requirements specified?Yes 0 No 0 N/A 0

19. Records and Documentation - Are requirements for record preparation, review, approval,retention, etc., adequately specified? Are all documents prepared in a clear legible manner suitable formicrofilming and/or other documentation storage method? Have all impacted documents been identified forupdate as necessary?Yes 0 No [3 N/A [D

20. Software Quality Assurance- ENN sites: For a calculation that utilized software applications (e.g.,GOTHIC, SYMCORD), was it properly verified and validated in accordance with EN- IT-104 orprevious site SQA Program?ENS sites: This is an EN-IT-104 task. However, per ENS-DC-126, for exempt software, was itverified in the calculation?Yes E) No [I N/A0

21. Has adverse impact on peripheral components and systems, outside the boundary of the documentbeing verified, been considered?Yes 0 No 0 N/A 0l

EN-DC-134, Rev. 2

ATTACHMENT 9.7Sheet I of 1

DESIGN VERIFICATION COMMENT SHEET

Comments / Continuation Sheet

Question Comments Resolution Initial/Date

# __________________________

___ I ___________ I __________ [ ______

4 4

4 4

4 4

EN-DC-134, Rev. 2

Attachment 2 to Enterqy Letter 2.11.040

Marked-Up TS Pages and BASES Pages

(7 Pages)

' 14ýPNPS

TABLE 3.2.B (Cant)

INSTRUMENTATION THAT INITIATES OR CONTROLS THE CORE AND CONTAINMENT COOLING SYSTEMS

Ivhiiiinurn oi of OpceiavulhrsLrmment Channels Per 46

Trip Syste. I il Trip Function Level Setling Remark

2 Condenrate Storage Tank Low Level > ove lank zero Provides interlock to Hsuction valves.

2 Suppiession Chamber High Level <- 1'1I" below torus zero

1 RCIC Turbine Steam Line High Flow s 300% of rated steam flow (2)

2 RCIC Turbine Compartment Wall IF 168F (2)

2 RCiC Exhaust Duct Torus Cavity .148F (2)

2 RCIC Valve Station Area Wall < 19a'F (2)

4 RCIC Stearn Line Low Pressure 77 > P > 63 psig (2)(5)(6)

1 HPCI Turbine Steam Line High Flow 5 296% of rated flow (3)

2 HPCI Turbine Comparnment Exhaust Duct -< 168rF '(3)

2 HPCI Exhaust Duct Torus Cavity < 198°F (3)

2 Hl-PCURIiR Valve Station Area Exhaust Duct - 13

S

PCI pump I

S 16 r

Aoleindinent No. Qj-"-4. i+9&3I42-1 314.2-16

LIMITING CONDITIONS FOR OPERATION

3.13 INSERVICE CODE TESTING

Applicability:

Applies to ASME Code Class 1, 2 and 3pumps and valves.

Objective:

To assure the operational readiness of ASMECode Class 1, 2, and 3 pumps and valves.

Specification:

A. Inservice Code Testina of Pumos and

SURVEILLANCE REQUIREMENTS

4.13 INSERVICE CODE TESTING

Apolicability:

Applies to the periodic testingrequirements of ASME Code Class 1, 2and 3 pumps and valves.

Obiective:

To assess the operational readiness ofASME Code Class 1, 2, and 3 pumps andvalves by performance of inservice tests.

'-I

Spoecification:A. Inservice Code Testing of Pump and

1.ValvesBased on the Facility CommercialOperation Date, Inservice Code Testingof ASME Code Class 1, 2 and 3 pumpsand valves shall be performed inaccordance with the Inservice CodeTesting Program.

Valves

1. The ASME OM Code terminology forInservice Test activities is as follows.

.1)CodeTerminology

WeeklyMonthlyQuarterly or

3 MthsSemiannually/

6 Mths9 MonthsYearly/AnnuallyBiannual/2 Yrs

Frequencies

7 Days31 Days92 Days

184 Days

276 Days366 Days732 Days

}JTýLt4I -ý t 7, 4

)Amendment No. 14-97, 222-1 3/4.1 3-1I

) LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS

3.13 INSERVICE CODE TESTIN •G 4.13 INSERVICE CODE TESTING

The provisions in Definitions (1.0) forREFUELING INTERVAL,SURVEILLANCE FREQUENCY, andSURVEILLANCE INTERVAL areapplicable to Code testing and to theabove frequencies for performing Coder7testing activities.

Performance of Code testing shall be in

addition to other specified SurveillanceRequirements.

K Nothing in the Inservice Code TestingI'• Program shall supersede therequirements of Technical Specifications.

6~ku

)

Amendment No. t3-4,-2-3-- 3/4.1!3-2

)

LIMITING CONDITIONS FOR OPERATION

3.3 REACTIVITY CONTROL (continued)

B. Control Rod Ocerability

LCO 3.3.B.1

SURVEILLANCE REQUIREMENTS

4.3 REACTIVITY CONTROL (continued)

B. Control Rod Operability

SR 4.3.B.1.1

(

Each control rod shall be OPERABLE.

APPLICABILITY:

RUN and STARTUP MODES; REFUELMODE when the reactor vessel head isfully tensioned. (See alsoo ý-

ACTIONS

---------------- NOTE ------- ---Separate condition entry is allowed foreach control rod.

A. One withdrawn control rod stuck.

--.---..-------- -- NOTE ------------------/- Rod Worth Minimizer (RWM) may be

bypassed as allowed by LCO 3.3.F.

1. Verify stuck control rodseparation criteria are metimmediately.

)

--..------------------ NOTE ----------------------Not required to be performed until 7 daysafter the control rod is withdrawn andthermal power is greater than the LPSP ofthe RWM.

Insert each fully withdrawn OPERABLEcontrol rod at least one notch once per 7days.

SR 4.3.B.1.2

---------------------- NOTE ----------------------Not required to be performed until 31 daysafter the control rod is withdrawn andthermal power is greater than the LPSP ofthe RWM.

Insert each partially withdrawnOPERABLE control rod at least one notchonce per 31 days.

SR 4.3.1.1.3

Verify each withdrawn control rod does notgo to the withdrawn overtravel position.

a. Each time the control rod iswithdrawn to "full out" position.

AND

b. Prior to declaring control rodOPERABLE after work on controlrod or CRD system that could affectcoupling.

SR 4.3.8.1.4

Verify each control rod scram time fromfully withdrawn to notch position 04 is; 7 seconds in accordance with

SR 4.3.C.1, SR 4.3.C.2, SR 4.3.C.3 orSR 4.3.C.4

SR 4.3.1.1.5

Determine the position of each control rodonce per 24 hours.

AND

2. Disarm the associatedcontrol rod drive (CRD)within 2 hours.

AND

3. Perform SR 4.3.B.1.1 andSR 4.3.8.1.2 for eachwithdrawn OPERABLEcontrol rod within 24 hoursfrom discovery ofcondition A concurrent withthermal power greater thanthe Low Power Setpoint(LPSP) of the RWM.

AND

4. Verify LCO 3.3.A.1 is metwithin 72 hours.

AND9)Amendment No. t86, 20, 3/4,3-2

%.

)BASES:3.10 CORE ALTERATIONS

W A. Refuelinq Interlocks

1. Refueling Equipment Interlocks

BACKGROUND

Refueling equipment interlocks restrict the operation of the refueling equipment orthe withdrawal of control rods to reinforce unit procedures that prevent the reactorfrom achieving criticality during refueling. The refueling interlock circuitry senses theconditions of the refueling equipment and the control rods. Depending on the sensedconditions, interlocks are actuated to prevent the operation of the refuelingequipment or the withdrawal of control rods.

One channel of instrumentation is provided to sense the position of the refuelingplatform, the loading of the refueling platform fuel grapple, and the full insert of allcontrol rods, except control rods withdrawn in accordance with LCO . or fullyinserted and disarmed. Additionally, inputs are provided for the loading of therefueling platform frame mounted hoist, the loading of the refueling platform monorailmounted hoist, the full retraction of the fuel grapple, and the loading of the serviceplatform hoist. With the reactor mode switch in the shutdown or refueling position,the indicated conditions are combined in logic circuits to determine if all restrictionson refueling equipment operations and control rod insertion are satisfied.

A control rod not at its full-in position interrupts power to the refueling equipment andprevents operating the equipment over the reactor core when loaded with a fuelassembly. Conversely, the refueling equipment located over the core and loaded

WV with fuel inserts a control rod withdrawal block in the Control Rod Drive System toprevent withdrawing a control rod.

The refueling platform has two mechanical switches that open before the platform orany of its hoists are physically located over the reactor vessel. All refueling hoistshave switches that open when the hoists are loaded with fuel.

The refueling interlocks use these indications to prevent operation of the refuelingequipment with fuel loaded over the core whenever any control rod is withdrawn, orto prevent control rod withdrawal whenever fuel loaded refueling equipment is overthe core.

To minimize the possibility of loading fuel into a cell containing no control rod, it isrequired that all control rods are fully inserted when fuel is being loaded into thereactor core. This requirement assures that during refueling the refueling interlocks,as designed, will prevent inadvertent criticality.

APPLICABLE SAFETY ANALYSES

A prompt reactivity excursion during refueling could potentially result in fuel failurewith subsequent release of radioactive material to the environment. Criticality and,therefore, subsequent prompt reactivity excursions are prevented during the insertionof fuel, Provided all control rods are fully inserted during the fuel insertion. Therefueling interlocks accomplish this by preventing loading of fuel into the core withany control rod withdrawn or by preventing withdrawal of a rod from the core during

4fuel loading.

.1• Refueling equipment interlocks satisfy Criterion 3 of 10 CFR 50.36(c)(2)(ii).

R-3vision ~B/~- B3 / 4. 1 () - I I

) BASES:

3.10 CORE ALTERATIONS (Cont)W A. Refueling Interlocks (Cont)

1. Refueling Equipment Interlocks (Cont)

SPECIFICATION 3.10.A.1 REQUIREMENTS

To prevent criticality during refueling, the refueling interlocks ensure that fuelassemblies are not loaded with any control rod withdrawn. To prevent theseconditions from developing, the all-rods-in, the refueling platform position, therefueling platform fuel grapple fuel loaded, the refueling platform frame mountedhoist fuel loaded, the refueling platform monorail mounted hoist fuel loaded, therefueling platform fuel grapple fully retracted position, and the service platform hoistfuel loaded inputs are required to be operable. These inputs are combined in logiccircuits, which provide refueling equipment or control rod blocks to preventoperations that could result in criticality during refueling operations.

The interlocks are required to be operable with the reactor mode switch locked in the"Refuel" position during in-vessel fuel movement with refueling equipment associatedwith the interlocks.

With one or more of the required refueling equipment interlocks inoperable (does notinclude the one-rod-out interlock addressed in Specification 3.1O.A.2), the unit mustbe placed in a condition in which the Specification does not apply or the interlocksare not needed. This can be performed by ensuring fuel assemblies are not movedin the reactor vessel or by ensuring that the control rods are inserted and cannot bewithdrawn.

Therefore, 3.1 O.A. 1.a requires that in-vessel fuel movement with the affectedrefueling equipment must be immediately (i.e., in a time frame consistent with safety)suspended. This action ensures that operations are not performed with equipmentthat would potentially not be blocked from unacceptable operations (e.g., loading fuelinto a cell with a control rod withdrawn). Suspension of in-vessel fuel movementshall not preclude completion of movement of a component to a safe position.

Alternately, 3.l O.A. 1.b requires that a control rod withdrawal block be inserted andthat all control rods subsequently verified to be fully inserted. This action ensuresthat control rods cannot be inappropriately withdrawn because an electrical orhydraulic block to control rod withdrawal is in place. To the extent practicable, in theevent of a failure(s) of an individual interlock, the effects of a failed interlock will beisolated to allow refueling activities to continue while the other interlocks aremaintained availaole. As a result, the unaffected interlocks will continue to providepartial protection. Like 3.10.A. l.a these actions ensure that unacceptable operationsare blocked (e.g., loading fuel into a cell with the control rod withdrawn).

. 4ý0

petA

Rqevision 232 ,93/41. !0-2

BASES:

3.10 CORE ALTERATIONS (Cont)

A. Refueling Interlocks (Cont)

2. Refuel Position One-Rod-Out Interlock

BACKGROUND

The refuel position one-rod-out interlock restricts the movement of co rol rods toreinforce unit procedures that prevent the reactor from becoming cri al duringrefueling operations. During refueling operations, no more than on control rod ispermitted to be withdrawn except as allowed by Specification .D.

The refuel position one-rod-out interlock prevents the selection of a second controlrod for movement when any other control rod is not fully inserted. It is a logic circuitthat has redundant channels. It uses the all-rods-in signal (from the control rod full-inposition indicators) and a rod selection signal (from the Reactor Manual ControlSystem).

APPLICABLE SAFETY ANALYSES

A prompt reactivity excursion durng refueling could potentially result in fuel failurewith subsequent release of radioactive material to the environment.The refuel position one-rod-out interlock and adequate shutdown margin preventcriticality by preventing withdrawal of more than one control rod. With one controlrod withdrawn, the core will remain subcritical, thereby preventing any prompt criticalexcursion.

The refuel position one-rod-out interlock satisfies Criterion 3 of 1 OCFR50.36(c)(2)(ii).

SPECIFICATION 3.10.A.2 REQUIREMENTS

To prevent criticality, the refuel position one-rod-out interlock ensures no more thanone control rod may be withdrawn. Therefore, the one-rod-out interlock must beoperaby when any control rod is withdrawn (except as allowed by Specification

S 3 •. ). The reactor mode switch must be locked in the refuel position to supportt thehe operability of the interlock.

With the refueling position one-rod-out interlock inoperable, the refueling interlocksmay not be capable of preventing more than one control rod from being withdrawn.This condition may lead to criticality. Therefore, control rod withdrawal must beimmediately suspended, and action must be immediately initiated to fully insert allcontrol rods in core cells containing one or more fuel assemblies. Action mustcontinue until all such control rods are fully inserted. Control rods in core cellscontaining no fuel assemblies do not affect the reactivity of the core and, therefore,do not have to be inserted.

B3/4.10-3 I