Text

License Amendment Request 261 Extended Power Uprate, Response to Request for Additional Information
	ML101200544
Person / Time
Site:	Point Beach
Issue date:	04/30/2010
From:	Meyer L; Point Beach
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	NRC 2010-0060
	Download: ML101200544 (256)
	v • d • e

April 30, 2010 NRC 2010-0060 10 CFR 50.90 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555 Point Beach Nuclear Plant, Units 1 and 2 Dockets 50-266 and 50-301 Renewed License Nos. DPR-24 and DPR-27 License Amendment Request 261 Extended Power Uprate Res~onseto Request for Additional Information

References:

(1) FPL Energy Point Beach, LLC letter to NRC, dated April 7, 2009, License Amendment Request 261, Extended Power Uprate (ML091250564)

(2) NRC electronic mail to NextEra Energy Point Beach, LLC, dated March 25, 2010, DRAFT - Request for Additional lnformation from Instrument and Control Branch Re: EPU (ML100840783)

NextEra Energy Point Beach, LLC (NextEra) submitted License Amendment Request (LAR) 261 (Reference I ) to the NRC pursuant to 10 CFR 50.90. The proposed license amendment would increase each unit's licensed thermal power level from 1540 megawatts thermal (MWt) to 1800 MWt, and revise the Technical Specifications to support operation at the increased thermal power level.

Via Reference (2), the NRC staff determined that additional information was required to enable the staff's continued review of the request. Enclosure 1 provides the NextEra response to the NRC staff's request for additional information. Enclosures 2 and 3 contain calculations that support the answer to question 2. Attachment E of Enclosure 2 contains reference information supporting the calculation. This information has not been included in this submittal because it is classified as proprietary by the manufacturer of the equipment, Westinghouse Electric Company and NextEra does not consider the reference information necessary to enable the review of the calculation. If the NRC determines that the reference information is required to complete its review, please contact Steve Hale at 5611691-2592 so the appropriate affidavits can be acquired by NextEra for release of the information.

This letter contains no new Regulatory Commitments and no revisions to existing Regulatory Commitments.

NextEra Energy Point Beach, LLC, 6610 Nuclear Road, Two Rivers, WI 54241

Document Control Desk Page 2 The information contained in this letter does not alter the no significant hazards consideration contained in Reference ( I ) and continues to satisfy the criteria of 10 CFR 51.22 for categorical exclusion from the requirements of an environmental assessment.

In accordance with 10 CFR 50.91, a copy of this letter is being provided to the designated Wisconsin Official.

I declare under penalty of perjury that the foregoing is true and correct.

Executed on April 30, 2010.

Very truly yours, NextEra Energy Point Beach, LLC M r r y Meyer Site Vice President Enclosure cc: Administrator, Region Ill, USNRC Project Manager, Point Beach Nuclear Plant, USNRC Resident Inspector, Point Beach Nuclear Plant, USNRC PSCW

ENCLOSURE 1 NEXTERA ENERGY POINT BEACH, LLC POINT BEACH NUCLEAR PLANT, UNITS 1 AND 2 LICENSE AMENDMENT REQUEST 261 EXTENDED POWER UPRATE RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION The NRC staff determined that additional information was required (Reference 1) to enable the Instrumentation and Control Branch to complete the review of License Amendment Request (LAR) 261, Extended Power Uprate (EPU) (Reference 2). The following information is provided by NextEra Energy Point Beach, LLC (NextEra) in response to the NRC staffs request.

EICB RAI-1 By letter date June 17, 2009 (Agencywide Documents Access and Management System Accession Number ML091690090) FPL Energy Point Beach, LLC, provided a response to Question 7. The response states The changes to the time delay relays for 4.16 kV and 480 V loss of voltage relays and the EDG [emergency diesel generator] breaker close delay relay are documented in a PBNP [Point Beach Nuclear Plant] calculation and is followed by a summary description of the calculation results. Please provide the relevant PBNP calculation including the analytical limit(s) and calculation of allowable value, nominal trip set point, total loop uncertainty, as-found tolerance and as-left tolerance for the technical specification changes to the time delay relays.

NextEra Response The requested calculation was provided in Enclosure 6 of Reference (3). Accordingly, this question was retracted by the NRC based on discussions with NextEra personnel on April 8, 2010.

EICB RAI-2 Provide a representative sample of the calculations for the setpoint changes being done under the review of the Extended Power Uprate. Include the analytical limit(s) and calculation of allowable value, nominal trip set point, total loop uncertainty, as-found tolerance and as-left tolerances.

Page 1 of 2

NextEra Response Four Instrumentation and Control (I&C) calculations were provided to the NRC in response to Question 3 of Reference (4). The previously provided I&C calculations include:

Pressurizer Pressure Instrument Loop Uncertainty and Setpoint

Turbine Impulse Pressure Low Power Permissive P-7 Instrument Scaling and Uncertainty

Containment Pressure Low Range

Auxiliary Feedwater Pump Low Suction Pressure Service Water Switchover and Pump Trip Instrument Loop Uncertainty and Setpoint In response to this request for additional information, two additional I&C calculations are provided as a representative sample of EPU setpoint changes in the following

Enclosures:

Enclosure 2 - Power Range Nuclear Instrumentation Uncertainty / Setpoint Calculation

Enclosure 3 - Steam Line Pressure Instrument Loop Uncertainty / Setpoint Calculation References (1) NRC electronic mail to NextEra Energy Point Beach, LLC, dated March 25, 2010, DRAFT - Request for Additional Information from Instrument and Control Branch Re: EPU (ML100840783)

(2) FPL Energy Point Beach, LLC letter to NRC, dated April 7, 2009, License Amendment Request 261, Extended Power Uprate (ML091250564))

(3) NextEra Energy Point Beach, LLC, letter to NRC, dated September 25, 2009, License Amendment Request 261, Extended Power Uprate, Response to Request for Additional Information (ML092750395)

(4) NextEra Energy Point Beach, LLC, letter to NRC, dated November 30, 2009, License Amendment Request 261, Extended Power Uprate, Response to Request for Additional Information (ML093360143)

Page 2 of 2

ENCLOSURE 2 NEXTERA ENERGY POINT BEACH, LLC POINT BEACH NUCLEAR PLANT, UNITS 1 AND 2 LICENSE AMENDMENT REQUEST 261 EXTENDED POWER UPRATE RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION POWER RANGE NUCLEAR INSTRUMENTATION UNCERTAINTY / SETPOINT CALCULATION 123 pages follow

Calculation No . 2009-0002 Revision 0 Page 5 of 83 Table of Contents BACKGROUND. PURPOSE. AND SCOPE O F CALCULATION ............................7 1.1 Background .............................................................................................................7 1.2 Purpose ....................................................................................................................

7 1.3 Purpose of This Revision ...................................................................................... 7 1.4 Scope ........................................................................................................................

7 1.5 Instrumentation Evaluated .................................................................................... 8 1.6 Superseded Station Calculations ........................................................................... 8 ACCEPTANCE CRITERIA ............................................................................................ 9 ABBREVIATIONS ......................................................................................................... 10 REFERENCES ................................................................................................................ 11 4.1 General ..................................................................................................................11 4.2 Drawings ................................................................................................................ 12 4.3 Procedures ............................................................................................................. 15 4.4 Vendor ...................................................................................................................16 4.5 Calculations ......................................................................................................... 16 ASSUMPTIONS .............................................................................................................. 18 5.1 Validated Assumptions ........................................................................................ 18 5.2 Unvalidated Assumptions .................................................................................... 20 DESIGN INPUTS ........................................................................................................... 21 6.1 Loop Definitions ................................................................................................... 21 6.2 Loop Block Diagram ............................................................................................ 21 6.3 Component Models and Tag Numbers ............................................................... 22 6.4 Environmental Considerations ........................................................................... 22 6.5 Analytical Limits (AL) and Field Trip Setpoints (FTSP) .................................25 METHODOLOGY ....................................................................................................... 26 7.1 Uncertainty Determination ................................................................................ 26 7.2 Limiting Trip Setpoint (LTSP) Equation Summary.........................................33 7.4 Drift Considerations ............................................................................................. 34 BODY O F CALCULATION .........................................................................................35

Calculation No . 2009-0002 Revision 0 Page 6 of 83 Table of Contents 8.1 Device Uncertainty Analysis ................................................................................35 8.2 Device Uncertainty Summary .............................................................................49 8.3 Total Loop Errors ................................................................................................52 8.4 Setpoint Evaluations.............................................................................................56 8.4 Setpoint Evaluations............................................................................................56 8.6 Acceptable As-Left and As-Found Calibration Tolerances .............................62 8.7 Channel Check Tolerance (CCT) ....................................................................... 69 9.0 RESULTS AND CONCLUSIONS. WITH LIMITATIONS ......................................70 9.1 Total Loop Error .................................................................................................. 70 9.2 Analytical Limits .................................................................................................. 70 9.3 Limiting Trip Setpoints. Operability Limits. and Recommended Tech Spec Changes ............................................................................................................. 70 9.4 Setpoint Evaluation .............................................................................................. 73 9.5 Acceptable As-Left and As-Found Tolerances ..................................................73 9.6 Channel Check Tolerance .................................................................................... 74 9.7 Limitations ............................................................................................................74 9.8 Graphical Representation of Setpoints ...............................................................75 10.0 IMPACT ON PLANT DOCUMENTS .......................................................................... 81 11.0 ATTACHMENT LIST ................................................................................................... 83 12.0 10 CFR 50.59 REVIEW .................................................................................................. 83

Calculation No. 2009-0002 Revision 0 Page 7 of 83

1.0 BACKGROUND

, PURPOSE, AND SCOPE OF CALCULATION

1.1 Background

The Power Range Neutron Flux instrumentation is part of the Nuclear Instruinentation System (NIS) which rnonitors reactor neutron flux at power. Four independent power range channels provide redundant monitoring of reactor power over a range of 0 - 120%

Rated Thermal Power (RTP). Each channel consists of two uncompensated ion chamber detectors, located above and below the core midplane, which allows for measurelnent of the total reactor power and the relative power distribution between the upper and lower halves of the core. The detector signals are processed by a series of modules located in control room raclts (or drawers) to provide protection, control, alarm, and indication functions (Ref. V. 1).

Each power range channel provides an input to two bistable relay divers, which feed the two-out-of-four logic matrices for the power range high neutron flux -low range and the power range high neutron flux - high range reactor trips. Separate bistable relay drivers also provide signals to the four permissive interlocks (P-7, P-8, P-9, and P-lo), which also feed two-out-of-fow logic matrices for actuation (Reference D.47).

1.2 Purpose The purpose of this calculation is to determine the power range instrument loop uncertainties and to evaluate the power range reactor trip setpoints, the power range pe~missivesetpoints, interlocks, alarms, and indicationhecording loops.

1.3 Purpose of This Revision This revision adds setpoint calculations for Extended Power Uprate (EPU) and adds Operability Limits for routine calibration. The revision also corrects an accuracy term for the NI drawer ineter that affects total loop elrors.

1.4 Scope The scope of this calculation is listed below:

9 Evaluate the existing Field Trip Setpoint (FTSP) for Power Range reactor trips, peimissives, rod stop, loss of detector voltage alarm, and rod drop alaim.

9 Determine uncertainties associated with the instrument loops for the setpoints and permissives, control board indication, recorder and PPCS loops under normal and accident enviromental conditions.

9 Determine Limiting Trip Setpoints for the reactor trips and peimissives 9 Determine Operability Limits for routine calibration.

9 Determine acceptable As-FoundlAs-Left Calibration Tolerances for the Power Range Drawer, Control Board Indicator, Recorder and PPCS.

9 Determine Channel Check Tolerance for Control Room Indicators.

Calculation No. 2009-0002 Revision 0 Page 8 of 83 1.5 Instrumentation Evaluated This calculation evaluates the plant equipment (for Units 1 and 2) listed in the table below. See Sections 6.2 and 6.3 of this calculation for instrument specifications, parameters, and loop configurations.

Table 1.5-1 Instrumentation List 1.6 Superseded Station Calculations Existing calculation PBNP-IC-38 should be superseded upon issuance of 2009-0002 Revision 0.

Calculation No. 2009-0002 Revision 0 Page 9 of 83 2.0 ACCEPTANCE CRITERIA Positive margin is required between the Limiting Trip Setpoint (LTSP) and the Field Trip Setpoint (FTSP) for primary trips. The LTSP is calculated to ensure that the instrument channel trip occurs at or before the associated Analytical Limit (AL) is reached. The LTSP is then compared to the FTSP to ensure that margin exists between the LTSP and the FTSP. Margin exists if the FTSP is less than the LTSP (for increasing setpoints) or the FTSP is greater than the LTSP (for decreasing setpoints). This criterion only applies to primary trips because backup trip functions and permissives lack an analytical limit and therefore are not required to trip at a particular value to support the accident analyses.

2.2 The Operability Limits calculated for primary trips must be at or more conservative than the colresponding Limiting Trip Setpoint. This will allow the Technical Specification tables for RF'S and ESFAS trip functions to be revised to insert the LTSPs as new Allowable Values for the primary trip functions but use the more restrictive Operability Limits for channel operability determination during surveillance (COT) testing.

2.3 Channel Check Tolerance (CCT) is the maximum expected deviation between channel indications when perfomling a qualitative assessment of channel behavior during operation. The calculated CCT will be compared to the existing CCT to ensure that the existing CCT is I the calculated CCT. If the existing CCT is non-conservative, a recommendation will be made to revise the existing CCT to satisfy the calculated CCT limit.

Calculation No. 2009-0002 Revision 0 Page 10 of 83 3.0 ABBREVIATIONS AL Analytical Limit AV Allowable Value CCT Channel Check Tolerance DAF Drawer As-Found Tolerance DAL Drawer As-Left Tolerance DBE Design Basis Event EQ Environmental Qualification FSAR Final Safety Analysis Report FTSP Field Trip Setpoint LTSP Limiting Trip Setpoint IAF Indicator As-Found Tolerance IAL Indicator As-Left Tolerance M&TE Measurement and Test Equipment NIS Nuclear Instrumentation System OL Operability Limit PBNP Point Beach Nuclear Plant PPCSAF PPCS As-Found Tolerance PPCSAL PPCS As-Left Tolerance PE Process Error PL Process Limit PPCS Plant Process Computer System PR Power Range PS Process Span (engineering unit)

RAD Radiation Absorbed Dose RAF Recorder As-Found Tolerance RAL Recorder As-Left Tolerance RCCA Rod Cluster Control Assembly RE Rack Error RTO Reactor Thermal Output RTP Rated Thelma1 Power RWAP Rod Withdrawal At Power RWFS Rod Withdrawal From Subcritical SLB(0C) Steam Line Break (Outside Containment)

SRSS Square Root of the Sum of the Squares Tech Spec Technical Specifications TLE Total Loop Error

Calculation No. 2009-0002 Revision 0 Page 11 of 83

4.0 REFERENCES

The revisions and/or dates of the References listed in this section are current as of 08/03/2007.

4.1 General G. 1 Point Beach Nuclear Plant Design Guideline DG-101, Instrument Setpoint Methodology, Rev. 4.

G.2 Point Beach Nuclear Plant Technical Specifications Section 3.3.1 and Bases B3.3.1, Amendment 201 (Unit I), 206 (Unit 2)

G.3 Point Beach Nuclear Plant FSAR Section 9.8.1 dated 06/07, Section 11.6 dated 06/03, Section 7.6 dated 06/07, Section 7.2 dated 08/05, Section 14.0 dated 06/03, Section 14.1.2 dated 0610 1, Section 14.2.6 dated 06/07, Section 14.1.1 dated 06/07 G.4 Not used G.5 Not used G.6 Not used G.7 Not used G.8 Not used G.9 ISA-RP67.04-02.2000 Methodologies for the Determination of Setpoints for nuclear Safety-related Instrumentation, Instlument Society of America G. 10 Not used.

G. 11 WCAP 13514, Rev. 1, Design Bases Document for the Wisconsin Electric Point Beach Nuclear Plant Reactor Protection System G. 12 Not used G. 13 Not used G. 14 Not used G. 15 Not used G. 16 Not used G. 17 Not used G. 18 Westinghouse Letter WEP-06-23, "Input for Current Analysis of Record (RPS/ESFAS)", dated March 28,2006.

G. 19 Not used G.20 WCAP-8587, Rev. 6-A, Methodology for Qualifying Westinghouse WRD Supplied NSSS Safety Related Electrical Equipment, dated March 1983.

G.21 Bechtel Specification No. 61 18-M-40, "Specification for Heating, Ventilating and Air Conditioning Controls", Rev. 1.

G.22 PB 634, Rev. 3, "Specification for Safety Assessment System and Plant Process Computer System for the Point Beach Nuclear Plant PPCS 2000".

G.23 WCAP-7669, "Topical Report, Nuclear Instrulnentation System", dated April 1971.

G.24 Not Used

Calculation No. 2009-0002 Revision 0 Page 12 of 83 G.25 WCAP-7116, "Precautions, Limitations, and Set Points for Nuclear Steam Supply Systems," dated October 1969 G.26 Westinghouse Report WEPB-PCS-NAP-FL-001-FS-02, "WEPB Plant Computer Replacement Project Functional Design Specification Document-Flow and Level Corrections", dated October 10,2001.

G.27 Westinghouse Report WEPB-PCS-NAP-IT-001-FS-02, "WEPB Plant Computer Replacement Project Functional Design Specification Document-Incore Thesmocouples", dated October 08,2001.

G.28 Passport Preventive Maintenance frequency check for Computer Analog to Digital Converters (located on DO80 panel under PMID 17263).

G.29 Walltdown for PBNP-IC-38, dated 1/30/07 (Attachment A)

G.30 PBF-2034, "Daily Logsheets - Unit 1" Pg. 82 - 84, Rev. 70 G.31 PBF-2035, "Daily Logsheets -Unit 2" Pg. 82 - 84, Rev. 70 G.32 Westinghouse Letter WEP-07-19, "Identification of Relevant Nuclear Instrumentation System Process Impact Terms" dated March 14,2007 G.33 PBNP Modification Request MR 98-002-C, "PPCS Changeover from Old to New PPCS", dated April 20, 2005 G.34 DIT CRR-I&C-012 "Treatment of Backup Trips and Permissives" Issued 6/4/07 (Attachment D)

G.35 NCP-26781, "Request for Technical Specification Change No. 7 Facility Operating Licenses DPR-24 and DPR-27 Point Beach Nuclear Plant" dated May 5, 1973 G.36 NPC-27238, "Modification to Technical Specification Change Request No. 7 Point Beach Nuclear Plant Unit Nos. 1 and 2 " dated April 11, 1975 G.37 NPC-35807, "Amendments Nos. 8 and 10 to Facility Operating Licenses Nos.

DPR-24 and DPR-27 for the Point Beach Nuclear Units 112" dated August 7, 1975 G.38 NUREG-143 1 Volume 1, Rev. 3.0, "Standard Technical Specifications Westinghouse Plants" June 2004 G.39 NPC 1999-05675-V3, "Point Beach Nuclear Plants Units 1 and 2 Technical Specifications Improvement Project" November 15, 1999 Volume 3 G.40 Westinghouse Letter WEP-09-2, "RPSWSFAS Safety Analysis Limit Setpoint Changes for the Point Beach Uprate Program", dated January 8,2009 G.41 Design Information Transmittal (DIT) CRR-I&C-014 dated 8/23/07, Supplement to Section 3.3.8 of PBNP Design Guide DG-I01 Rev 4, Methodology to determine the Operability Limit 4.2 Drawings D.l Not used D.2 1045F074 Sh. 1-5, "NIS Remote Wiring Connections" Unit 2 Rev. 1 1045F074 Sh. 6, 8, "NIS Remote Wiring Connections" Unit 2 Rev. 2 1045F074 Sh. 7, "NIS Remote Wiring Connections" Unit 2 Rev. 5 D.3 1045F078 Sh. 1,3,5, 8, "NIS Remote Wiring Connections" Unit 1 Rev. 2 1045F078 Sh. 2,4, 6, "NIS Remote Wiring Connections" Unit 1 Rev. 1

Calculation No. 2009-0002 Revision 0 Page 13 of 83 1045F078 Sh. 7, "NIS Remote Wiring Connections" Unit 1 Rev. 4 D.4 Not used D.5 5651D045, Westinghouse "Nuclear Instrunlentation System Detector Connections", Rev. 1 D.6 206C061 Sh. 1, "MCB C04 Annunciation Cab. 1A & 2B" Rev. 17 206C061 Sh. 2, "MCB C04 Annunciation Cab. 1A & 2B" Rev. 13 D.7 605 1D060 Sh. 1, Westinghouse "NIS Console Colnpactor & Rate Drawer Assernbly" Rev. 2 1 605 1D060 Sh. 2, Westinghouse "NIS Console Compactor & Rate Drawer Assembly" Rev. 13 6051D060 Sh. 3, Westinghouse "NIS Console Colnpactor & Rate Drawer Assembly" Rev. 18 6051D060 Sh. 4, Westinghouse "NIS Console Compactor & Rate Drawer Assembly" Rev. 12 D.8 6051D076 Sh. 1, 3, "NIS Console Misc. Control & Indication Panel", Rev. 3 60510076 Sh. 2, "NIS Console Misc. Control & Indication Panel", Rev. 4 D.9 6054D015 Sh. 1 - 4, "NIS Console out Line" Rev. 3 D. 10 Not used D . l l Not used D.12 Not used D. 13 Not used D.14 883D195 Sh. 12, "NIS Pelmissive and Bloclcs" Rev. 10 D. 15 E-1223E-A, "Wiring Diagram Main Control Board Section 1C04 -Front - CPR04

- Vertical Section" Unit 1, Rev. 11 D. 16 E-1227E-B, "Wiring Diagram Main Control Board Section 1C04 - Rear - CPR03" Unit 1, Rev. 7 D. 17 E- 1226E-B, "Wiring Diagram Main Control Board Section 1C04 - Rear - CPRO 1" Unit 1, Rev. 5 D.18 E-94 Sh. 48, "Connection Diagram - Local Control Boards & Racks - Nuclear Rack #1C130" Unit 1, Rev. 17 D. 19 E-94 Sh. 49, "Connection Diagram - Local Control Boards & Racks - Nuclear Raclc#lC131" Unit 1, Rev. 15 D.20 E-94 Sh. 50, "Connection Diagram - Local Control Boards & Raclts - Nuclear Rack #1C132" Unit 1, Rev. 16 D.21 E-94 Sh. 51, "Connection Diagram - Local Control Boards & Raclts -Nuclear Rack #1C133" Unit 1, Rev. 16 D.22 E-99 Sh. 5, "Connection Diagram Penetration 1Q18, 1Q23, 1Q51, 1Q53, 1Q54" Unit 1, Rev. 10 D.23 E-1579E-A, "Wiring Diagram Main Control Board Section 2C04 - Front - CPR62

- Vertical Section" Unit 2, Rev. 8

Calculation No. 2009-0002 Revision 0 Page 14 of 83 D.24 E-1583E-A, "Wiring Diagram Main Control Board Section 2C04 -Rear -

CPR59" Unit 2, Rev. 8 D.25 E-1582E-A, "Wiring Diagram Main Control Board Section 2C04 -Rear -

CPR01" Unit 2, Rev. 7 D.26 E-2094 Sh. 48, "Connection Diagram - Local Control Boards & Raclts - Nuclear Rack #2C133" Unit 2, Rev. 20 D.27 E-2094 Sh. 49, "Connection Diagram - Local Control Boards & Raclcs -Nuclear Rack #2C132" Unit 2, Rev. 14 D.28 E-2094 Sh. 50, "Connection Diagram - Local Control Boards & Raclts -Nuclear Rack #2C13 1" Unit 2, Rev. 16 D.29 E-2094 Sh. 5 1, "Connection Diagram - Local Control Boards & Racks - Nuclear Rack #2C13OWUnit 2, Rev. 16 D.30 E-2099 Sh. 5, "ConnectionDiagram Penetration 2Q18,2Q23,2Q51,2Q53,2Q54" Unit 2, Rev. 8 D.31 Not Used D.32 0082, Sh. 10, "Cable Spreader Room Air Conditioning System Rack C58," Rev. 9 0.33 617F354 Sh. 4A1, "Schematic Diagram - Inputs Reactor Protection Systeln Train "A" Unit 1" Rev. 3 D.34 617F354-2 Sh. 4A1, "Schematic Diagram - Inputs Reactor Protectioil System Train "A" Unit 2" Rev. 4 D.35 617F354 Sh. 4A2, "Schematic Diagram - Inputs Reactor Protection System Train "A" Unit 1" Rev. 3 D.36 617F354-2 Sh. 4A2, "Schematic Diagram - Inputs Reactor Protection Systeln Train "A" Unit 2" Rev. 2 D.37 617F354 Sh. 4B1, "Schematic Diagram -Inputs Reactor Protection System Train "B" Unit 1" Rev. 3 0.38 617F354-2 Sh. 4B1, "Schematic Diagram - Inputs Reactor Protection System Train "B" Unit 2" Rev. 6 D.39 617F354 Sh. 4B2, "Schematic Diagram -Inputs Reactor Protection Systein Train "B" Unit 1" Rev. 3 D.40 617F354-2 Sh. 4B2, "Schematic Diagram - Inputs Reactor Protection System Train "B" Unit 2" Rev. 2 D.41 499B466 Sh. 1012, "Elementary Wiring Diagram Block Auto. Rod Withdraw -

Unit 1" Rev. 3 D.42 499B466 Sh. 1013, "Elementary Wising Diagraln Block Man. Rod Withdraw -

Unit 1" Rev. 3 D.43 499B466 Sh. 1212, "Elementary Wiring Diagram Block Auto. Rod Withdraw -

Unit 2" Rev. 1 D.44 499B466 Sh. 1213, "Elementaty Wiring Diagram Block Man. Rod Withdraw -

Unit 2" Rev. 1

Calculation No. 2009-0002 Revision 0 Page 15 of 83 D.45 195A778 Sh. 20, "Miscellaneous Relay Elementary Diagram 1C 138 - Unit 1" Rev. 3 D.46 195A778 Sh. 30, "Miscellaneous Relay Elementary Diagram 2C 158 -Unit 2" Rev. 3 D.47 883D195 Sh. 11, "NIS Trip Signal Logic" Rev. 7 4.3 Procedures P.l Not used P.2 Not used P.3 lICP 02.007 "Nuclear Instrumentation Power Range Channels 92 Day Channel Operational Test" Rev. 10 P.4 Not used P.5 21CP 02.007 "Nuclear Instrumentation Power Range Channels 92 Day Channel Operational Test" Rev. 12 P.6 Not used P.7 Not used P.8 Not used P.9 Not used P. 10 Not used P . l l Not used P.12 Not used P.13 Not used P.14 Not used P.15 Not used P. 16 0-TS-RE-001 "Power Level Dete~mination"Rev. 13 P. 17 0-TS-RE-002 "Power Range Detector Power Level Adjustment" Rev. 5 P.18 lICP 02.022 "Nuclear Instrumentation Systeln Power Range Channels Shutdown Operational Test" Rev. 8 P.19 21CP 02.022 "Nuclear Instrulnentation Systeln Power Range Channels Shutdown Operational Test" Rev. 7 P.20 lICP 04.026RD "Nuclear Instrumentation Power Range Red Channel N41 Outage Calibration and ECAD Testing" Rev. 2 P.21 lICP 04.026WH "Nuclear Instrumentation Power Range White Channel N42 Outage Calibration and ECAD Testing" Rev. 2 P.22 lICP 04.026BL "Nuclear Instrumentation Power Range Blue Channel N43 Outage Calibration and ECAD Testing" Rev. 2 P.23 IICP 04.026YL "Nuclear Instrumentation Power Range Yellow Channel N44 Outage Calibration and ECAD Testing" Rev. 2

Calculation No. 2009-0002 Revision 0 Page 16 of 83 P.24 21CP 04.026RD "Nuclear Instrumentation Power Range Red Channel N41 Outage Calibration and ECAD Testing" Rev. 3 P.25 21CP 04.026WH "Nuclear Instrumentation Power Range White Channel N42 Outage Calibration and ECAD Testing" Rev. 3 P.26 21CP 04.026BL "Nuclear Instrumentation Power Range Blue Channel N43 Outage Calibration and ECAD Testing" Rev. 3 P.27 21CP 04.026YL "Nuclear Instrumentation Power Range Yellow Channel N44 Outage Calibration and ECAD Testing" Rev. 4 P.28 ICI 12, "Selection of M&TE for Field Calibrations" Rev. 8 P.29 ICP 5.51, "Secondary Vacuum Instruments" Rev. 12 P.30 RE1 40.0, "Pre-Startup Calibration of the Nuclear Instrument Detectors" Rev. 7 4.4 Vendor V.l Westinghouse Nuclear Instrumentation System - Book 1, VTM #00193-1, Rev. 37, Sections 1.0 and 2.0 V.2 Westinghouse Main Control Board - Part 1, PBNP VTM #00132A, Rev. 25 -

Westinghouse I.L. 43-252C, "252 Line Switchboard Edgewise Instruments, Five Inch Classification".

V.3 Westronics Strip Chart Recorder, PBNP VTM #00596, Rev. 4 - Westronics User Manual M0100086-01.4, "Series 4200 Continuous Writing Recorder" V.4 Combustion Engineering, Inc. 1485-ICE 1234, Rev. 2, "Functional Design Description for Seismic Safety Parameter Display System (SSPDS)", PBNP VTM

01209, Book 4, Rev. 21.

V.5 Westinghouse letter RRS-VICO-02-689 dated 12/4/2002, "NIS Analog Meters" (Attachment E to this calculation)

V.6 Combustion Engineering, Inc. 1485-ICE 1239, Rev. 2, "Functional Design Description for Safety Assessment System and Plant Process Computer System",

PBNP VTM # 01209, Book 5 - Rev. 21.

V.7 Combustion Engineering, Inc., "SAS/PPCS Computer System - Volume 21 -

Manual Reinstated 5/30/03 Equipment in Plant", PBNP VTM #01055U, Revision 11, Tab F, "RTP7436/10 Digital and Analog Loopback and Calibration Card."

V.8 Johnson Controls Temperature Coinposite Book 2, VTM # 00309B, Rev. 5, dated 8/15/94 - T-4000 Series Pneumatic Room Thermostats (Tab - Thennostats &

Thermometers).

V.9 User Guide I-FP 34401A Multimneter, VTM #01692, Rev. 0 V. 10 Imaging and Sensing Technology Corporation Technical Manual NY-WL-24154, Power Range Uncompensated Ionization Chamber VTM# 00193-3 Rev. 0 4.5 Calculations C. 1 PBNP-IC-07, Rev. 0, "Westinghouse 252 Indicator Drift Calculation" C.2 Engineering Evaluation No. 2005-0006, Rev. 0, "Drift Calculations Evaluation"

Calculation No. 2009-0002 Revision 0 Page 17 of 83 C.3 CN-CRA-02-42, Rev. 0, "Point Beach Steamline Break Mass & Energy Release Outside Containment Analysis for Power Uprate" C.4 CN-CPS-08-20, Rev. 0, "Plant Operability Margin to Trip and EOC Coastdown Analysis for Point Beach Units 1 and 2 Extended Power Uprate Program" C.5 CN-TA-08-52, Rev. 0, "Partial Loss of Flow Permissive P-8 Setpoint Analysis for Point Beach Extended Power Uprate (EPU)"

C.6 CN-TA-08-55, Rev. 0, "Point Beach Units 1 and 2 Rod Withdrawal at Power Analysis (RWAP) for the Extended Power Uprate Program"

Calculation No. 2009-0002 Revision 0 Page 18 of 83 5.0 ASSUMPTIONS 5.1 Validated Assumptions 5.1.1 It is assumed that the accuracy of the PPCS display loop is k 0.5 1 % of full scale.

This accuracy value applies to the loop from the PPCS analog input field terminations to the PPCS printed and/or display output devices. The accuracy value includes the teinperature effect, power supply effect, humidity effect, radiation effect, seismic (vibration) effect, and drift over the entire PPCS normal operating range.

Basis: Per Reference G.22, the PPCS replacement modification shall process inputs and outputs from existing UO devices. As such, the existing signal processing I10 isolation and signal conversion cards were not replaced as a result of Modification Request 98-002 (Ref. G.33). References V.4 and V.6 document that the maximum total system ell-or for the old PPCS computer system, during normal operating environments, from field terininations to the printed and/or display output, shall be within t 0.5 % of the full scale (excluding errors before input of the analog input).

A review of all Westinghouse Plant Computer Replacement Reports revealed that the output values for all newly installed PPCS equipment (not including the existing 110 devices discussed in the above paragraph) shall be within 0.1 % of hand calculated results, with the following two exceptions:

1) For results based on polynomial curves, the output values shall be within 1.0 %

of hand calculated results (Reference G.26).

2) For results based on steam tables, the output values shall be within 0.5 % of hand calculated results (References G.26 and G.27).

The PPCS points considered in this calculation display Reactor Thermal Power Level as a percentage based on a 0 - 5 Vdc input signal from the loop rack components. Since the Power Range loop is not a component of References G.26 or G.27, accuracy values associated with polynomial curves and steain tables are not applicable, and the accuracy of the newly installed PPCS equipment (not including the existing 110 devices) is considered to be 0.1 %.

Therefore, to determine the overall PPCS system accuracy, the specified values of 0.1 % (for newly installed PPCS equipment) and 0.5 % (for existing PPCS equipment) are combined using the SRSS methodology as follows:

In accordance with Section 3.3.3.3 of Reference G.1, if the manufacturer does not specify environmental errors associated with the subject normal environmental accuracy ratings, these effects are considered to be included in the specified accuracy ratings or are considered to be negligible.

Calculation No. 2009-0002 Revision 0 Page 19 of 83 Per Reference V.7, the PPCS analog-to-digital (AID) converters have a drift value o f f 0.01 % for a period of 1 year. This value is not significant when compared to the much larger accuracy value o f f 0.5 1 %. Per Reference G.28, the AID converters are calibrated approximately eveiy 36 weeks to eliminate any potential drift. In addition, these components historically never need to be calibrated because they do not drift. Therefore, the vendor specified drift value is considered negligible.

Per Section 3.3.3.15 of Reference G. 1, in the absence of a vendor specified drift value; it is typical for the device accuracy to be substituted in place of drift.

However, in the case of PPCS, considering an additional f 0.5 1 % for calculating the As-Found Tolerance would create a value large enough to allow PPCS degradation to go undetected. Conversely, by assuming that the drift value is included in the accuracy value, the As-Found Tolerance would remain tight enough to detect PPCS degradation prior to system failure. Therefore, the PPCS drift is conservatively encompassed by the f 0.5 1 % accuracy value.

5.1.2 It is assumed that the maximum environmental temperature of Control Room and Computer Room instrumentation is 120 OF.

Basis: Table 6-1 of WCAP-8587 (Ref. G.20) states that when the HVAC is non-safety related, the normal temperature of 120 OF should be used. Since the Control Rooin and Coinputer Room HVAC Systein chiller is not powered from an essential power bus, the Control Room and Computer Room HVAC System is considered as a non-safety related system.

5.1.3 It is assumed that the As-Left setting tolerances for instruments evaluated in this calculation are as follows:

Sensor: NIA (not calibrated)

Power Range Drawer: f 0.5% RTP (Indication)

It 1.O% RTP (Trips)

+0, -1% RTP (Permissives) i 0.025 Vdc (Calibration)

Recorder: f 1 .OO mVdc Control Board Indicator: + 1.0% RTP PPCS: f 0.6% RTP Basis: These As-Left setting tolerance values have historically provided acceptable instrument performance and consistency in the calibration program.

These As-Left setting tolerances are routinely achievable for the installed instruments, consistent with safety limits and test equipment capability. They are currently used in practice at the station, and implemented by calibration procedures listed in References P.3, P.5, and P.20 - P.27. As-Found setting tolerances are to be detei~ninedin this calculation.

Calculation No. 2009-0002 Revision 0 Page 20 of 83 5.1.4 It is assumed that the Power Range detector uncertainties of accuracy, drift, power supply, temperature, humidity, and radiation are negligible.

Basis: Per Section 1.2 of Appendix C, the daily calibration of the power range channels (References G.30 and G.3 1) accounts for the sensor accuracy, drift, power supply, temperature, huinidity, and radiation. Any uncertainties associated with the calibration are considered as process ei-rors to this calculation (Ref. G.32).

5.1.5 It is assumed that the maxilnuin environmental operating temperature for the existing installed PPCS system is 95 O F .

Basis: Reference G.33 (Attachments 1 and 5) identifies that the inost temperature sensitive component of the new PPCS system is the non-ruggedized Sparc computer, which has an operating temperature limit of 95 OF. Note: the maximum temperature used for evaluating PPCS uncertainties is 85 O F , which is bounded by the PPCS operating temperature limit.

5.2 Unvalidated Assumptions

Calculation No. 2009-0002 Revision 0 Page 21 of 83 6.0 DESIGN INPUTS 6.1 Loop Definitions The Power Range Monitoring Loops (channels) analyzed in this calculation are shown in block diagram format in Figure 6.2-1 and explained in more detail in Sections 6.2 and 6.3.

6.2 Loop Block Diagram The block diagram below (Figure. 6.2-1) shows the component configuration for the Power Range instrument loops that are addressed in this calculation. The diagram is generic and applies to loops N-41 through N-44 (Ref. D.5-D.30, and V.l).

Dropped Rod Isolation Alarm NM 301 Overpower Relay Driver Rod Stop Permissive Circuit P9 Uncompensated Ion Chamber Permissive Detector Circuit P8 (Dual Section)

Low Range High Level Trip Bistable High Range Relay Driver High Level Trip Permissive Relay Driver Circuit P71P10' Indicator (Control Room)

Isolation Amplifier NM 303 Recorder Bistable Loss of Relay

- Driver -+ Detector Drawer NC 307 Voltage Alarm

Permissives P7 and P10 share a comnlon bistable relay driver with the same setpoint, but different functions (Reference V. 1 and Attachment C).

Figure 6.2-1 Block Diagram of Power Range Circuit

Calculation No. 2009-0002 Revision 0 Page 22 of 83 6.3 Component Models and Tag Numbers The following table identifies components shown in Figures 6.2-1 for each of the Power Range instrument loops and provides the associated plant infol~nationfor use throughout this calculation.

Table 6.3-1, Power Range Instruments ag Number I Input I Output I Reference(s) 1 Uncompensated Ion Detector MODEL #I384 N-44 DET Summing Level Westinghouse - 3.6 x lo" P.20 - P.27 0 - 10 Vdc An~plifier* NM3 10 amps N-4 1A/B (2) 0 - 5 Vdc Isolation Westinghouse N-42MB (1) 0 - 1 nlAdc p.20 - p.27 N-43MB '-lo Vdc Amplifier* NM303 (1) 0 - 50 mVdc N-44MB (1) 0 - 10 Vdc Bistable Relay Westinghouse V. 1 0-10 Vdc Digital Contacts Driver* NC301 -NC308 4 1B, NI-42B P.20 - P.27 0- 10 Vdc 0 - 120%

..- 43B, NI-44B Control Board Westronics P.20 - P.27 NR-45 0-50 mVdc 0 - 120%

Recorder 4200 Series N41, N42 P.20 - P.27 PPCS N/A 0-5 Vdc 0 - 120%

N43, N44

- Grouped as Power Range Drawer 6.4 Environmental Considerations As stated in Section 1.1, above, the power range instlumentation perfoims protection, control, alarm, and indication functions. Attachment C explains that only normal environmental conditions need to be considered for the power range protection functions.

Although neutron flux is classified by PBNP as a Regulatory Guide 1.97 variable, the combination of source and intermediate ranges covers lo-" amps to 100% rated power with one decade of overlap. Therefore, the power range is not considered in RG 1.97. In addition, a separate Wide Range Flux Monitoring System (N-40), not in the scope of this calculation, is environmentally qualified for post accident conditions and would also be available for post-accident monitoring. The power range control, alarm, and indication functions are required only during llormal plant operation - therefore, only nomal environmental conditions need to be considered for these functions also.

The devices used in the power range instrument loops are located in the Containment, Computer Room, or Control Room. Therefore, the environmental conditions in each of these areas are discussed.

Calculation No. 2009-0002 Revision 0 Page 23 of 83 6.4.1 Containnient Per Reference D.29, the Power Range Sensors are located in containment. These detectors are located in the priinary shield wall, external to the reactor (Ref. G.3)

Per Ref. G.20, the Containment Building nlaxiinum no~malteinperature inside the secondary shield wall is 135°F. Reference G.20 also states that the ininilnuln is 65°F and the Containment Building maximum nolmal humidity is 70%. Per Attachment C, the detector location is exposed to 5 x lo4R/hr.

Table 6.4-1, Containment Environmental Conditions Per Attachment C and Assumption 5.1.4, the detectors are calibrated daily, thus negating any uncertainty due to normal containment environmental conditions.

6.4.2 Control Room and Computer Room The PR drawers, indicators, PPCS, and the recorder are located in the control room or computer rooin (Ref. D.15 - D.21 and D.23 - D.29).

The Control Rooin HVAC System controls the temperature of the Control Room and the Computer Room at 75 OF per Reference G.21. Per FSAR Section 9.8.1 (Ref. G.3), the temperature can valy f 10 OF. This temperature variation is supported by the fact that the Johnson Controls T-4002-202 thermostat (Ref.

D.32) in the Control Room is capable of controlling the room temperature within these bounds (Ref.V.8). Therefore, per Section 3.3.4.7 of Ref. G. 1, the minimum temperature of 65 OF is used as the calibration temperature for the components in the Control Room and Computer Room.

Since the indicator, PPCS, and recorder are only required during normal plant operating conditions, 85°F is used as the maximum teinperature (Per Assumption 5.1.5, the maximum operating temperature of the PPCS is 95°F). Per Assumption 5.1.2, the maximum nol~naltemperature is 120 OF. This maximum temperature is used and justified by the intended functions of the High Flux Reactor Trip loop (primary trip). This function necessitates the instrumentation to operate under compromised environmental conditions caused by a loss of the HVAC cooling unit.

The Control Room humidity of 50 % is documented in Ref. G.20. FSAR Section 11.6.2, fifth paragraph (Ref. G.3) states that the control room is in Zone I and Table 11.6-1 (Ref. G.3) states the maximum dose rate in Zone I is 1.0 inreln/hr.

Calculatio~lNo. 2009-0002 Revision 0 Page 24 of 83 Table 6.4-2. Control Room and Conlputer Room Environmental Conditions Table 6.4-3, Summary of Environmental Conditions Related. When HVAC is lost, to evaluate above 85°F.

Related. When HVAC is lost, this loop is not operable. No need to evaluate above 85°F.

Calculation No. 2009-0002 Revision 0 Page 25 of 83 6.5 Analytical Limits (AL), Process Limits, and Field Trip Setpoints (FTSP)

The Analytical Limits and Field Trip Setpoints for the High Neutron flux reactor trips at culrent power and for EPU are given in Table 6.5-1 below:

Table 6.5-1, Reactor Trip Limits and Setpoints The Process Limits and Field Trip Setpoints for permissives are given in Table 6.5-2 below:

Table 6.5-2, Permissive Setpoints

Calculation No. 2009-0002 Revision 0 Page 26 of 83 7.0 METHODOLOGY 7.1 Uncertainty Determination The uncertainties and loop el-sors are calculated in accordance with Point Beach Nuclear Plant's Instrument Setpoint Methodology, DG-I01 (Ref. G. 1). This methodology uses the square root of the sum of the squares (SRSS) method to combine random and independent essors, and algebraic addition of non-random or bias essors. Clarifications to this methodology are noted below:

A) Treatment of 95/95 and 75/75 Values To convert 95/95 uncertainty values to 75/75 unceltainty values (when applicable);

this calculation uses the conversion factor specified in Section 3.3.3.13 of Reference G. 1. All individual instrument uncertainties are evaluated and shown as 95/95 values, and are combined under the Total Loop Ei-sor radical as such.

Conversion to a 75/75 value is performed after the 95/95 TLE radical is computed.

B) Treatment of Significant Digits and Rounding This uncertainty calculation will adhere to the rules given below for the treatment of numerical results.

1. For values on the order of lo2 or less, the rounding of discrete calculated instrument uncertainties (e.g. reference accuracy, temperature effect, etc.)

should be performed such that the numerical value is restricted to three (3) or less digits shown to the right of the decimal point.

For example, an uncertainty calculated as 0.6847661 should be listed (and cassied through the remainder of the calculation) as 0.685.

An uncertainty calculated as 53.235487 should be listed (and cal-sied thsough the remainder of the calculation) as 53.235.

2. For values less than lo3, but greater than or equal to lo2, the rounding of discrete calculated instrument uncertainties (e.g. reference accuracy, temperature effect, etc.) should be performed such that the numerical value is restricted to two (2) or less digits shown to the right of the decimal point.

For example, an uncertainty calculated as 131.6539 should be listed (and carried thsough the remainder of the calculation) as 131.65.

3. For values greater than or equal to lo3, the rounding of discrete calculated instrument uncertainties (e.g. reference accuracy, temperature effect, etc.)

should be performed such that the numerical value is restricted to one (1) or less digits shown to the right of the decimal point.

For exanlple, an uncertainty calculated as 225 1.4533 should be listed (and carried through the remainder of the calculation) as 225 1.5.

4. For Total Loop Uncertainties, the calculated result should be rounded to the numerical precision that is readable on the associated loop indication or recorder. If the loop of interest does not have an indicator, the Total Loop Error should be rounded to the numerical precision currently used in the associated calibration procedure for the end device in that loop (e.g. trip unit or alai~nunit).

Calculatioll No. 2009-0002 Revision 0 Page 27 of 83

5. For calibration tolerances, the calculated result should be rounded to the numerical precision cussently used in the associated calibration procedure.

These rules are intended to preserve a value's accuracy, while minimizing the retention of insignificant or meaningless digits. In all cases, the calculation prepares shall exercise judgment when rounding and carsying numerical values, to ensure that the values are kept practical with respect to the application of interest.

C) Determination of Channel Check Tolerance (CCT)

Per Section 3.3.8.7 of Reference G.1, the CCT value is considered a 75/75 value.

However, converting the CCT from 95/95 into a 75/75 value restricts the tolerance allowed for the indication loop devices and essentially makes it illore difficult for the plant to ~neettheir requirements. This approach is considered to be overly conservative. Therefore, this calculation will determine CCT as a 95/95 value.

Although Reference G.l does not discuss the rounding techniques for CCT values, it is typical for tolerance values to be rounded down. This approach tightens the tolerance band, thus creating a conservative tolerance value. However, in the case of CCT, when a channel is determined non-operational, it is most likely to be found grossly out of tolerance, i.e., the difference between the channel readings far surpasses the allowable CCT value. Therefore, in an effort to reduce the occunence of false out of tolerance CCT readings, this calculation will round the CCT value up to the precision that is readable on the indication device.

7.1.1 Sources of Uncertainty Per Ref. G. 1, the device uncertainties to be considered for normal environmental conditions include the following:

Sensor Accuracy Sensor Drift Sensor M&TE Sensor Setting Tolerance Sensor Power Supply Effect Sensor Temperature Effect Sensor Humidity Effect Sensor Radiation Effect Sensor Seismic Effect Power Range Drawer Accuracy Power Range Drawer Drift Power Range Drawer M&TE Power Range Drawer Setting Tolerance Power Range Drawer Power Supply Effect Power Range Drawer Temperature Effect Power Range Drawer Humidity Effect Power Range Drawer Radiation Effect Power Range Drawer Seismic Effect

Calculation No. 2009-0002 Revision 0 Page 28 of 83 Indicator Accuracy (14 Indicator Drift (Id)

Indicator M&TE (11n)

Indicator Setting Tolerance (Iv)

Indicator Power Supply Effect UP)

Indicator Tenlperature Effect (It)

Indicator Humidity Effect (Ih)

Indicator Radiation Effect (1s)

Indicator Seismic Effect (1s)

Indicator Readability Effect (Irea)

Recorder Accuracy (Ra)

Recorder Drift (Rd)

Recorder M&TE (Rm)

Recorder Setting Tolerance (Rv)

Recorder Power Supply Effect (RP)

Recorder Temperature Effect (Rt)

Recorder Humidity Effect (a)

Recorder Radiation Effect Recorder Seismic Effect (Rs)

Recorder Readability Effect (Rsea)

PPCS Accuracy (PPCSa)

PPCS Drift (PPCSd)

PPCS M&TE (PPCSm)

PPCS Setting Tolerance (PPCSv)

PPCS Power Supply Effect (PPCSP)

PPCS Temperature Effect (PPCSt)

PPCS Humidity Effect (PPCSh)

PPCS Radiation Effect (PPCSr)

PPCS Seismic Effect (PPCSs)

PPCS Readability Effect (PPCSrea)

Process Error (PE)

Bias Terms (Bias)

The uncertainties will be generally calculated in percent of span and converted to the process units as required.

Per Sections 3.1 and 3.2 of Reference G. 1, the functions of the Power Range Neutron Flux monitors are classified into the following categories:

The Power Range High Flux Reactor Trip Setpoints, which provide inputs to RPS, are classified as Category A function. The total loop error should be expressed as 95/95 (95% probability at a 95% confidence level) value.

The Control Room indication total loop error, which is non-safety related, is classified as Category E function. The total loop error should be expressed as a 75/75 value.

Calculation No. 2009-0002 Revision 0 Page 29 of 83 The recorder and PPCS display, which only provides data inonitoring function and is non-safety related, is classified as Category E function.

The total loop essor should be expressed as a 75/75 value.

Per Section 3.3.3.13 of Ref. G. 1, the uncertainties listed above are considered two-sigma values (95% probability/95% confidence) unless otherwise specified.

7.1.2 Total Loop Error Equation Summary The general equation for total instrument loop error found in Ref. G. 1, Section 3.3.7 is modified in order to calculate each function individually.

7.1.2.1 Total Trip Loop Error (TLET~lp) Equation Summary Per Section 6.4, only nollnal operating environmental conditions are considered. Per Figure 6.2-1, the total loop error for the Power Range High Flux trips (High and Low Range) consist of the following uncertainties:

7.1.2.2 Total Indication Loop Error (TLEIND)Equation Summary Per Section 6.4, only normal operating environmental conditions are considered. Per Figure 6.2-1, the total loop error for the Power Range Neutron Flux Indicator consists of the following uncertainties:

s a 2 + D a 2 + 1 a 2 + S d 2 + ~ +Id2 d2

+ ~ r n ~ + ~ r n , ~ + ~ r n ~ + ~ v ~ + ~ v ~ ~ +

TLE,,, = + I V ~ + S ~ ~ + D ~ ~ + I ~+Biases ~ + S ~ (Eq.7.1.2.2)

~ + D ~ ~ +

1t2 + s h 2 + D h 2 + 1 h 2+ s r 2 + ~ r ' +

,Ir2+~s2+~~2+~~2+1read2+~~2 7.1.2.3 Total PPCS Loop Error (TLEPPCS) Equation Summary Per Section 6.4, only normal operating environmental conditions are considered. Per Figure 6.2-1, the total loop error for the Power Range Neutron Flux PPCS display consists of the following uncertainties:

Calculation No. 2009-0002 Revision 0 Page 30 of 83 s a 2 +Da2+ PPCS~'+ sd2 + Dd2 + PPCS~'

+ Sm2 + Dm,' + P P C S ~ +' SV' + DV,' + PPCSV' TLE,,,, = f + sp2 + Dp2+ PPCS~'+ st' + ~ t +'PPCS~'+ +Biases (eq, 7.1.2.3)

\ sh2+ Dh2+ PPCS~'+ s r 2+ Dr' + PPCS~'+

I SS' + Ds2 + PPCSS' + P P C S ~ + ~ PE'

~'

7.1.2.4 Total Recorder Loop Error (TLEREC) Equation Summary Per Section 6.4, only normal operating environmental conditions are considered. Per Figure 6.2-1, the total loop error for the Power Range Neutron Flux Recorder consists of the following uncertainties:

7.1.3 As-Found Tolerance Equation Summary As-Found Tolerances are calculated independently for each of the loop components. The equations shown are adapted from Section 3.3.8.6 of Reference G. 1 for use in this calculation.

7.1.3.1 Power Range Drawer As-Found Tolerance (DAF)

The acceptable As-Found Tolerance for the Power Range Drawer is calculated by the following equation:

DAF = k JDV' + ~ d +' ~ m ' (Eq. 7.1.3.1)

Where:

Dv = Power Range Drawer Setting Tolerance Dd = Power Range Drawer Drift Dm = Power Range Drawer M&TE El-ror (DM, or DM2) 7.1.3.2 Indicator As-Found Tolerance (IAF)

The acceptable As-Found Tolerance for the Indicator is calculated by the following equation:

Calculation No. 2009-0002 Revision 0 Page 31 of 83 (Eq. 7.1.3.2)

Where:

Iv = Indicator Setting Tolerance Id = Indicator Drift 1111= Indicator M&TE Error 7.1.3.3 PPCS As-Found Tolerance (PPCSAF)

The acceptable As-Found Tolerance for the PPCS is calculated by the following equation:

PPCSAF = i- ~ P P C S V + ' PPCS+ ~ P~ P C S ~(Eq.

~ 7.1.3.3)

Where:

PPCSv = PPCS Setting Tolerance PPCSd = PPCS Drift PPCSm = PPCS M&TE Eiror 7.1.3.4 Recorder As-Found Tolerance (RAF)

The acceptable As-Found Tolerance for the Recorder is calculated by the following equation:

R A F = ~J R V ~ + ~ d ~ + ~ m ~ (Eq. 7.1.3.4)

Where:

Rv = Recorder Setting Tolerance Rd = Recorder Drift Rm = Recorder M&TE Eiror 7.1.4 As-Left Tolerance Equation Summary Per Section 3.3.8.6 of Reference G.l, the As-Left Tolerances are calculated independently for the coinponents in the loop.

7.1.4.1 Power Range Drawer As-Left Tolerance (DAL)

The As-Left Tolerance for the Power Range Drawer is equal to the setting tolerance:

DAL =fDv (Eq. 7.1.4.1)

Where:

Dv = Power Range Drawer Setting Tolerance

Calculation No. 2009-0002 Revision 0 Page 32 of 83 7.1.4.2 Indicator As-Left Tolerance (IAL)

The As-Left Tolerance for the Indicator is equal to its setting tolerance:

IAL = f Iv (Eq. 7.1.4.2)

Where:

Iv = Indicator Setting Tolerance 7.1.4.3 PPCS As-Left Tolerance (PPCSAL)

The As-Left Tolerance for the PPCS is equal to its setting tolerance:

PPCSAL = + PPCSv (Eq. 7.1.4.3)

Where:

PPCSv = PPCS Setting Tolerance 7.1.4.4 Recorder As-Left Tolerance (RAL)

The As-Left Tolerance for the Recorder is equal to its setting tolerance:

RAL =fRv (Eq. 7.1.4.4)

Where:

Rv = Recorder Setting Tolerance 7.1.5 Operability Limit (OL) Equation Summary Per Section 3.3.8.2 of Reference G.41, the Operability Limit (OL) is defined as a calculated limiting value that the As-Found bistable setpoint is allowed to have during a Technical Specification surveillance Channel Operational Test (COT),

beyond which the insti-ument channel is considered inoperable and corrective action must be taken. Two OLs are calculated, one on each side of the FTSP as-left tolerance band, incorporating a calculated 3-sigma (30) drift value. A channel found drifting beyond its 30 drift value is considered to be operating abnormally (i.e., is inoperable).

Per Section 3.3.8.4 of Reference G.41, the OL on each side of the FTSP is calculated as follows:

OL+ = FTSP + [RAL2 + ~d~:] " (Eq. 7.1.5-1)

OL- = FTSP - [RAL2 + ~ d 3 2 "] (Eq. 7.1.5-2)

Calculation No. 2009-0002 Revision 0 Page 33 of 83 the FTSP is expressed in percent of span OL+is the Operability Limit above the FTSP OL- is the Operability Lilnit below the FTSP RAL is the rack as-left tolerance (typically the bistable tolerance)

Rd3, is the 30 rack drift value determined as follows:

The rack drift value (Rdz,) is the 2-sigma drift value for components checked during the COT, typically the bistable drift.

7.1.6 Channel Check Tolerance (CCT)

Per Reference G. 1, the channel check tolerance (CCT) represents the maximum expected deviation between channel indications that monitor the same plant process parameter. The CCT is determined for the instrument loops that require a qualitative assessment of channel behavior during operation. This assessment involves an observed comparison of the channel indicatiodstatus.

As stated in Section 3.3.8.7 of Reference G.l, the CCT is determined by combining the reference accuracy (a), setting tolerance (v), drift (d), and readability (sea) of each device, including the sensor, in the indication loop. A channel checlc involves a comparison of the two indications independent of the number of redundant loops. The channel check tolerance is the combination of these uncel-tainties (in % span) using the SRSS method shown below:

+ Iv 2 +1rea2),,, + ( s a 2 + D a 2 + 1a2 + s d 2 + Dd2 + 1d2 (Eq. 7.1.6)

+ s v 2 + D V +~I V +he82)indb

~

7.2 Limiting Trip Setpoint (LTSP) Equation Summary Per Section 3.3.8.4 of Reference G.l, when a setpoint is approached fsom one direction and the random uncertainties are nonnally distributed, a reduction factor of 1.64511.96 =

0.839 may be applied to a 95/95 (95% probability at a 95% confidence level) TLE. The reduction factor should only be applied to the random portion of the TLE that has been statistically derived using the SRSS method. Therefore, this caIculation separates the TLE into random and bias terms in order to apply the reduction factor solely to the random portion of the TLE.

For a process increasing toward the analytical limit, the calculated Limiting Trip Setpoint is as follows:

For a process decreasing from n o ~ ~ noperation al toward the analytical limit, the calculated Limiting Trip Setpoint is determined as follows:

Calculation No. 2009-0002 Revision 0 Page 34 of 83 Drift Considerations The drift values established in Reference C. 1 will be utilized for the indicators.

Use of the aforementioned drift value (as design input to this calculation) is based on justification provided by Engineering Evaluation 2005-0006 (Ref. C.2). This evaluation reviews the station's M&TE and M&TE control programs, based on requirements imposed by the methodology used to prepare instrument setpoint and uncertainty calculations for the station (Ref. G. 1). The evaluation concludes that the station's M&TE and M&TE control programs have remained equivalent or improved since the drift calculations were initially prepared, and therefore, renders the drift calculations acceptable for use in current (present-day) calculation revisions performed for the station.

Calculation No. 2009-0002 Revision 0 Page 35 of 83 8.0 BODY OF CALCULATION 8.1 Device Uncertainty Analysis This section will introduce all applicable uncertainties for the devices that comprise the Power Range Neutron Flux monitoring loop shown in Figure 6.2-1.

From Ref. G. 1 (Section 3.3.4.3), the drift values calculated froin As-FoundJAs-Left instsuinent calibration data noi~nallyinclude the ell-or effects under normal conditions of drift, accuracy, power supply, plant vibration, calibration temperature, normal radiation, nonnal humidity, M&TE used for calibration, and instrument readability. If it is deteimined that the calibration conditions are indicative of the normal operating conditions, the environmental effects need not be included separately. All device uncertainty tenns are considered ralldom and independent unless othelwise noted.

8.1.1 Sensor Accuracy (Sa)

Per Assumption 5.1.4, the accuracy of the sensor is negligible. Therefore, Sa =

0.000% span 8.1.2 Sensor Drift (Sd)

Per Assumption 5.1.4, the drift of the sensor is negligible. Therefore, Sd =

0.000% span 8.1.3 Sensor M&TE (Sm)

Per References P.20 - P.27, the Sensors are uncalibrated devices. Therefore, there is no error due to calibration equipment.

Sm =

0.000% span 8.1.4 Sensor Setting Tolerance Effect (Sv)

Per References P.20 - P.27, the Sensors are uncalibrated devices. Per References P. 16 and P. 17 the sensor output is compared against the Daily Power Calorimetric. Any enor associated with the sensor power level adjustment is accounted for in the Power Caloriinetric portion of t11e process enor (Section 8.1.49). Therefore, Sv = It 0.000% span 8.1.5 Sensor Power Supply Effect (Sp)

Per Assumption 5.1.4, the power supply effect of the sensor is negligible.

Therefore, Sp = It 0.000% span 8.1.6 Sensor Temperature Effect (St)

Calculation No. 2009-0002 Revision 0 Page 36 of 83 Per Assumption 5.1.4, the temperature effect of the sensor is negligible.

Therefore, St = h 0.000% span 8.1.7 Sensor Humidity Effect (Sh)

Per Assumption 5.1.4, the humidity effect of the sensor is negligible. Therefore, Sh = It 0.000% span 8.1.8 Sensor Radiation Effect (Sr)

Per Assumption 5.1.4, the radiation effect of the sensor is negligible. Therefore, Sr =

0.000% span 8.1.9 Sensor Seismic Effect (Ss)

There is no seismic effect provided by the vendor for the Power Range Drawer (Ref. V.l). Per Section 3.3.4.10 of Reference G.1, the effects of seismic or vibration events for non-mechanical instsumentation are considered zero unless vendor or industry experience indicates othenvise. Therefore, Ss =

0.000% span 8.1.10 Power Range Drawer Accuracy (Da)

+

The Power Range (PR) Drawer accuracy is 2.0 % full scale (Ref. V. 1). This accuracy is interpreted to include all modules inside the drawer (see Table 6.3-1) through which the neutron flux signals from the sensor are processed. Therefore, Da = f 2.000 % Span 8.1.11 Power Range Drawer Drift (Dd)

The vendor does not provide a drift specification for the PR Drawer (Ref. V. 1).

Per Section 3.3.3.15 of Reference G. 1, when drift is not specified by the vendor, the accuracy of the component is used as the drift for the entire calibration period. Therefore, Dd = f 2.000 % Span 8.1.12 Power Range Drawer M&TE (Dml, Dm2)

The PR Drawer is calibrated using the drawer Test Calibration Module (NM3 12),

which has an accuracy of IfI 0.5% as read on an ion current meter for each channel (Ref. V.5). This module supplies the input to the summing amplifier for high and low range. Per Reference V. 1, the summing amplifier averages the two signals and the output is read on the percent power indicator located on the

Calculation No. 2009-0002 Revision 0 Page 37 of 83 drawer. Because of this, the ell-ors for each signal (high and low) prior to the sulnming amplifier could be propagated through an averaging function per Reference G.9. However, it can be shown that it is more conservative to calculate these errors for one signal (high a low) following the standard lnethodology as opposed to propagating the ell-ors for both signals to deternline a combined ell-or. As a result, the errors are calculated without propagation for use in this calculation. Therefore, the M&TE Ell-or is the accuracy of the test module combined with the readability errors due to reading the input current and output percent power.

Ma = + 0.5% span Completed procedures of RE1 40.0 (Ref P.30) can be used to show that the current range for power neutron flux is within 0 - 500 yA. For this range, the calibration module is set to input 0.5 milliamps as read on the indicator. Per Section 3.3.4.4 of Reference G.l, the readability of an analog device for M&TE is l/q its minor division. Per Reference G.29, at the 0.5 mA scale, the input cull-ent meter has minor divisions eveiy 0.005 milliamp. Therefore, Mrea, = 0.250% span Per Section 3.3.4.4 of Reference G.l, the readability of an analog device for M&TE is !A its minor division. Per Reference G.29, the output percent level meter has minor divisions every 1% RTP with a span of 120% RTP. Therefore, Mrea2 =+ 1/4

1% RTP * (100% span/l20% RTP)

Mrea2 = 0.208% span The total M&TE uncertainty for the calibration of the Power Range Drawer is calculated using the multiple M&TE equation given in Section 3.3.4.4 of Reference G. 1:

Dml = + 0.596% span While calibrating the power range drawer, the output of the sulnming amplifier is also read. The M&TE essor of the multiplier should also be considered (Note, this is applicable only for the calculation of the As-Found Tolerances with Vdc output).

Calculation No. 2009-0002 Revision 0 Page 38 of 83 Per References P.20 - P.27, the power range drawer suiming amplifier output is measured with a multiineter capable of nleasuring 0 - 10 Vdc output. According to calibration procedure ICI-12 (Ref. P.28), the following M&TE are capable of performing this ineasureinent.

Flulte 45 inultimeter (slow resolution, 5-digit display, 10 Vdc range):

RA,,, = f 0.025% reading RAIllt, = f 0.025% reading

10 Vdc RA,,,, = f 0.0025 Vdc U s t d =0 RDnlte = f 6 DG

0.001 Vdc RD,,,, = f 0.006 Vdc From Section 3.3.4.4 of Reference G. 1, M&TE uncertainty is calculated using the following equation:

m,, = f40.0025' + 0' + 0.006' =f0.0065Vdc HP 34401A multimeter (6.5 digit display. 10 Vdc range) (Ref. V.9):

RA,,,, = + (0.0035 % reading + 0.0005 % range)

RA,,, =+ [0.0035 % (10 Vdc) + 0.0005 % (10 Vdc)]

RA,,, = + 0.0004 Vdc U s t d =0 RD,,,,, =f 0.00001 Vdc From Section 3.3.4.4 of Reference G.l, M&TE uncertainty is calculated using the following equation:

~ H P = f40.0004~ 0' + + 0.00001' =+ 0.0004 Vdc For conservatism, the uncertainty of the Fluke 45 is used for the output M&TE error for reading the Power Range Drawer level amplifier output.

Converting the uncertainty to % span, q5 = (ui~certainty/calibratedspan)

100%

~5 =(f 0.0065 VdcIlO Vdc) " 100%

nh5 =f 0.065 % span The total M&TE uncertainty is from the calibration module, the readability of the input current indicator on the drawer, and the inultimeter used to measure the output of the summing amplifier. Therefore, using the multiple M&TE equation given in Section 3.3.4.4 of Reference G.1:

Calculation No. 2009-0002 Revision 0 Page 39 of 83 Dmz = f0.563% span 8.1.13 Power Range Drawer Setting Tolerance (Dvl, Dvz, Dv3)

Per References P.20 - P.27 and Assuinption 5.1.3, the PR Drawer setting

+

tolerance is 0.50% RTP as read on l(2)N-41A- l(2)N-44A. This is the setting tolerance associated with calibrating the drawer for output to the indicator, recorder, and PPCS. However, at the output to the bistable relays for trips and permissives, the drawer has a setting tolerance of 1.0% RTP. Therefore, this setting tolerance is used in determining the tolerances for these purposes. Since the scale of RTP is 0 - 120% RTP (Ref. G.29), these values must be converted to process span.

Indication Dvl = f0.50% RTP Dv, = f0.50% RTP * (100% span/l20% RTP)

Dv, = f 0.417% span Dvz = i:1 .O% RTP Dv2 = f1.O% RTP * (100% span/l20% RTP)

Dvz = f 0.833% span Calibration Dv3 = f 0.025 Vdc Dv3 = i:0.025 Vdc * (100% span/10.000 Vdc)

Dv3 = f 0.250% span 8.1.14 Power Range Drawer Power Supply Effect @p)

The vendor does not specify a power supply effect for the power range drawer (Ref. V. 1). Section 3.3.3.16 of Reference G. 1 states that industry experience with similar devices should be considered in the absence of vendor data. Review of similar devices from the same vendor does not provide power supply effect information. Therefore, the power range drawer power supply effect is considered negligible.

Calculation No. 2009-0002 Revision 0 Page 40 of 83 Dp =

0.000% span 8.1.15 Power Range Drawer Temperature Effect (Dt)

Per Reference V. 1, the power range drawer has an ambient temperature range of 40°F - 120°F. Per Section 6.4, the inaximuin temperature range the power range drawer is expected to operate is 65°F - 120°F. Per Section 3.3.3.3 of Reference G. 1, in the absence of vendor specified temperature effects, the temperature ell-or is negligible as long as enviromnental conditions ineet the vendor specified requirements. Therefore, Dt =

0.000% span 8.1.16 Power Range Drawer Humidity Effect (Dh)

Per Section 3.3.3.20 of Reference G.l, changes in ambient humidity have a negligible effect on the uncertainty of the instruments used in this calculation.

Therefore, Dh =

0.000% span 8.1.17 Power Range Drawer Radiation Effect (Dr)

The power range drawer is located in the Control Room, which has a mild radiological environment under all plant conditions. Per Section 3.3.3.21 of Reference G. 1, radiation ersors are considered to be included in the drift error.

Therefore, Dr =

0.000% span 8.1.18 Power Range Drawer Seismic Effect @s)

There is no seismic effect provided by the vendor for the power range drawer (Ref. V. 1). Per Section 3.3.4.10 of Reference G. 1, the effects of seismic vibration events for non-mechanical instruinentation are considered zero unless vendor or industiy experience indicates othenvise. Therefore, Ds = =t0.000% span 8.1.19 Indicator Accuracy (Ia)

Reference C. 1 has determined the historical drift values for the indicator. Per Reference G. 1, when drift error values have been statistically derived from As-FoundIAs-Left calibration data, the Accuracy of the indicator is included in the drift value. Therefore, Ia = ): 0.000 % span

Calculation No. 2009-0002 Revision 0 Page 41 of 83 8.1.20 Indicator Drift (Id)

Per References P.20 - P.27, the power range indicators are Westinghouse 252 and they are calibrated individually. Reference C. 1 is the As-FoundJAs-Left drift analysis for Westinghouse HX-252 indicators that are either string calibrated with Foxboro 66BC-0 isolators or individually calibrated. Although the drift analysis performed in Reference C. 1 does not specifically include the As-FoundAs-Left data of the power range indicator, the 95/95 drift value calculated for individually calibrated Westinghouse HX-252 indicator therein is considered representative of the indicators experienced at PBNP. Since the power range indicators are tested and calibrated every 18 months (Ref. P.20 and P.27), the loo%, 2-year 9519.5 drift value (Table 8.2 of Ref. C.l) is conservatively used.

Therefore, Id = f 1.028 % span Bias = 4 0.000 % span 8.1.21 Indicator M&TE Effect (Im)

Reference C.l has determined the historical drift values for the indicator. Per Reference G.l, when drift error values have been statistically derived from As-FoundAs-Left calibration data, the M&TE Effect of the indicator is included in the drift value. Therefore, Im = f 0.000 % span 8.1.22 Indicator Setting Tolerance (Iv)

Per References P.20 - P.27 and Assumption 5.1.3, the setting tolerance of the power range indicators is 1.O% RTP. Therefore, Iv = *1 .O% RTP * (100% span/l20% RTP)

Iv =

0.833 % span 8.1.23 Indicator Power Supply Effect (Ip)

Reference C. 1 has determined the historical drift values for the indicator. Per Reference G. 1, when drift error values have been statistically derived from As-FoundAs-Left calibration data, the Power Supply Effect of the indicator is included in the drift value. Therefore, Ip = f 0.000 % span 8.1.24 Indicator Temperature Effect (It)

Per Section 6.4.3, the indicators are located in the Control Room, which is environmentally controlled between 65 O F and 120 OF. The vendor infor~nation (Ref. V.2) does not provide temperature effects for the indicators. Per Reference G.27, the temperature effect is included in the drift value. Therefore,

Calculation No. 2009-0002 Revision 0 Page 42 of 83 It = f 0.000 % span 8.1.25 Indicator Humidity Effect (Ih)

Per Section 3.3.3.20 of Reference G.1, changes in ambient humidity have a negligible effect on the uncertainty of the instruments used in this calculation.

Therefore, Ih = f 0.000 % span 8.1.26 Indicator Radiation Effect (Ir)

Per Section 6.4.3, the indicators are located in the Control Room, which has a mild radiological environment under all plant conditions. Reference C. 1 has determined the historical drift values for the indicator. Per Reference G. 1, when drift error values have been statistically derived from As-FoundAs-Left calibration data, the Radiation Effect of the indicator is included in the drift value. Therefore, Ir = + 0.000 % span 8.1.27 Indicator Seismic Effect (Is)

There is no seismic effect provided by the vendor for the indicators (Ref. V.2).

From Section 6.4, only normal plant operating conditions are evaluated.

Therefore, Is = f 0.000 % span 8.1.28 Indicator Readability Effect (Irea)

Reference C. 1 has determined the historical drift values for the indicator. Per Reference G. I, when drift error values have been statistically derived from As-FoundAs-Left calibration data, the Readability Effect of the indicator is included in the drift value. Therefore, Irea = f 0.000 % span 8.1.29 PPCS Accuracy (PPCSa)

Per Assuinption 5.1.1, the PPCS accuracy is t- 0.5 10% span. Therefore, PPCSa = rt 0.510% span 8.1.30 PPCS Drift (PPCSd)

Per Assumption 5.1.1, the drift for the PPCS is included in the accuracy term.

Therefore,

Calculation No. 2009-0002 Revision 0 Page 43 of 83

+

PPCSd = 0.000% span 8.1.31 PPCS M&TE Effect (PPCSm)

Per References P.20 - P.27, the PPCS is calibrated by ineasuriilg an input voltage (0 - 5 Vdc) from the power range drawer and observing the output on the PPCS.

The readability of the PPCS is accounted for in Section 8.1.38. Therefore, the M&TE effect of the PPCS is due to the ~nultiinetermeasuring the input voltage.

Per Reference P.28, the following M&TE are capable of this measusenlent.

HP 34401A multimeter (6.5 digit display, 10.0 Vdc range) (Ref. V.9)

RAmte u m t e RAmte

= k (0.0035 % reading + 0.0005 % range) k f0.0035 % (5 Vdc) + 0.0005 % (10 Vdc)]

= k 0.000225 Vdc u s t d =0 m m t e = k 0.00001 Vdc From Section 3.3.4.4 of Reference G.1, M&TE uncertainty is calculated using the following equation:

Fluke 45 multiineter (5 digit display, 30 Vdc range)

RAmte = uncertainty

max reading

+

Urn,, = 0.025% reading

5Vdc RAn~te = i 0.00125 Vdc u s t d =0 m m t e = _+ 2 DGTS

0.001 Vdc m m t e = i 0.002 Vdc From Section 3.3.4.4 of Reference G.l, M&TE uncertainty is calculated using the following equation:

m,, = f d0.00125' + 0' + 0.002' =k 0.00236Vdc Fluke 8842A multimeter (6.5 digit display, 20 Vdc range)

RAnltc *

= uncertainty max reading RAn,te "

= +0.0035% reading 5 Vdc RAtllte = f 0.000175 Vdc RAstd =O m m t c = t2 DGTS " 0.0002 Vdc RDtntc = + 0.0002 Vdc

Calculation No. 2009-0002 Revision 0 Page 44 of 83 Frorn Section 3.3.4.4 of Reference G.l, M&TE uncertainty is calculated using the following equation:

The uncertainty of the Fluke 45 (14, = & 0.00236 Vdc) is used as the bounding M&TE because it is the less accurate.

Converting to % span, PPCSm = + 0.00236 Vdc * (100% spad5 Vdc)

PPCSm = f 0.047% span 8.1.32 PPCS Setting Tolerance (PPCSv)

Per References P.20 - P.27 and Assumption 5.1.3, the setting tolerance for the PPCS is + 0.6% RTP. Therefore, PPCSv = & 0.6% RTP * (100% spadl20% RTP)

PPCSv = h 0.500 % span 8.1.33 PPCS Power Supply Effect (PPCSp)

Per Assumption 5.1.1, the power supply effect for the PPCS is included in the accuracy term. Therefore, PPCSp = k 0.000 % span 8.1.34 PPCS Temperature Effect (PPCSt)

Per Assumption 5.1.1, the temperature effect for the PPCS is included in the accuracy tern. Therefore, PPCSt = + 0.000 % span 8.1.35 PPCS Humidity Effect (PPCSh)

Per Assurnption 5.1.1, the humidity effect for the PPCS is included in the accuracy term. Therefore,

+

PPCSh = 0.000 % span

Calculation No. 2009-0002 Revision 0 Page 45 of 83 8.1.36 PPCS Radiation Effect (PPCSr)

Per Assumption 5.1.1, the radiation effect for the PPCS is included in the accuracy term. Therefore, PPCSr = +_ 0.000 % span 8.1.37 PPCS Seismic Effect (PPCSs)

Per Assumption 5.1. l , the seismic effect for the PPCS is included in the accuracy term. Therefore,

+

PPCSs = 0.000 % span 8.1.38 PPCS Readability Effect (PPCSrea)

Section 3.3.5.3 of Reference G.l states that the readability ersor for digital indication is the least significant digit. Per References P.20 - P.27, the power range PPCS display is readable to at least 0.1% RTP. Therefore, PPCSrea =

0.1% RTP * (100% span/l20% RTP)

PPCSrea =

0.083% span 8.1.39 Recorder Accuracy (Ra)

Per Reference V.3, the accuracy of analog recording for an input range of 50

+

mVdc is 0.25 % of full scale. The vendor also specifies a repeatability of rfi. 0.1

% of full scale for voltage input signals. Section 3.3.4.1 of Reference G.l states that the accuracy term includes the combined effects of the repeatability.

Therefore, Ra = +_ 0.250 % span 8.1.40 Recorder Drift (Rd)

The vendor specifications (Ref V.3) do not provide a drift allowance. Per Section 3.3.3.15 of Reference G. 1, when drift is not specified by the vendor, the accuracy of the component is used as the drift for the entire calibration period. Therefore, Rd = + 0.250 % span 8.1.41 Recorder M&TE Effect @m)

Per References P.20 - P.27, the Recorder is calibrated by measuring the output froin the power range drawer on the recorder. Therefore, the M&TE effect of the recorder is due to the inultimeter measuring the input voltage. Per Reference P.28, the following M&TE are capable of this measurement.

Flulte 45 inultiineter (medium resolution, 5-digit display, 300 inVdc range):

Calculation No. 2009-0002 Revision 0 Page 46 of 83 RA,,, = + 0.025% reading RA,,,,, = + 0.025% reading

50 mVdc RA,,,,, = t 0.0125 Vdc RAstd =0 RD,,, = + 2 DG

0.01 Vdc RD,,, = f 0.02 Vdc From Section 3.3.4.4 of Reference G.1, M&TE uncertainty is calculated using the following equation:

m,, = id0.0125' + 0' + 0.02' =+ 0.0236 mVdc HP 34401A multilneter (6.5 digit display, 100 rnVdc range) (Ref. V.9):

RA,,,, = + (0.0050 % reading + 0.0035 % range)

RA,,,, = t [0.0050 % (50 mVdc) + 0.0035 % (100 mVdc)]

RA,,, = st 0.006 mVdc u s t d =0 RD,,, = + 0.0001 mVdc Froin Section 3.3.4.4 of Reference G. 1, M&TE uncertainty is calculated using the following equation:

For conservatism, the uncertainty of the Fluke 45 is used for the input M&TE for the recorder Rm = * (0.0236 mVdc / 50 mVdc)

100 % span Rm = rt 0.047 % span 8.1.42 Recorder Setting Tolerance (Rv)

Per References P.20 - P.27, and Assumption 5.1.3, the setting tolerance of the recorder is 1.OO mVdc with a range of 0 - 50 mnVdc. Therefore, Rv = .t 1.00 mVdc * (100% spad50 mnVdc)

Rv = rt 2.000% span 8.1.43 Recorder Power Supply Effect (Rp)

The vendor does not provide power supply effect specifications for the recorder (Ref. V.3). Section 3.3.3.16 of Ref. G. 1 states that industry experience with similar devices should be considered in the absence of vendor data. Review of similar devices from the same vendor does not provide power supply effect

Calculation No. 2009-0002 Revision 0 Page 47 of 83 information. Therefore, the Recorder Power Supply Effect is considered negligible.

Rp =5 0.000 % span 8.1.44 Recorder Temperature Effect (Rt)

Per Section 6.4, the Recorder is located in the Control Room, which has an ambient temperature between 65 OF and 85 OF. From vendor infoimation (Ref.

V.3), the Recorder has an operating range of +32 OF to +I22 OF with no associated temperature effect. Therefore, the temperature effect is considered negligible.

Rt = + 0.000 % span 8.1.45 Recorder Humidity Effect (Rh)

Per Section 3.3.3.20 of Reference G.1, changes in ambient humidity have a negligible effect on the uncertainty of the instruments used in this calculation.

Therefore, Rh = If: 0.000 % span 8.1.46 Recorder Radiation Effect (Rr)

The recorder is located in the Control Room, which has a mild radiological environment under all plant conditions. Per Section 3.3.3.21 of Reference G.1, radiation errors are considered to be included in the drift error. Therefore, Rr = + 0.000 % span 8.1.47 Recorder Seismic Effect (Rs)

There is no seismic effect provided by the vendor for the recorders (Ref. V.3).

Per Section 6.4, only normal plant operating conditions are evaluated. Therefore, Rs = rt 0.000 % span 8.1.48 Recorder Readability Effect (Rrea)

Section 3.3.5.3 of Reference G.l states that the readability error for an analog device is % the minor division. Per Reference G.29, the minor division on the recorder is 1% RTP. Therefore, Rrea = h [%

1% RTP] * (100% span/l20% RTP)

Rrea =

0.417% span

Calculation No. 2009-0002 Revision 0 Page 48 of 83 8.1.49 Process Error (PE)

Per Reference G.32, the process el-sor for the power range is a factor of the Power Caloriinetric uncertainty, uncertainty due to Downcolner Temperature, and the Radial Power Distribution uncertainty. These are all treated as random el-rors and are combined using the SRSS method. Therefore, where, PEP = Power Calorimetric Error PED = Downcolner Temperature Error PER = Radial Power Distribution Error From Reference G.32, PEP =

2.0% RTP PED =

0.45% RTP,

4.99% RTP PER = i4.0% RTP For conservatism, the worst case Downcomer Temperature Error is used.

PE =

6.70 % RTP Converting to % span, PE = i 6.70% RTP * (1 00% span/l20% RTP)

PE = & 5.583% span

Calculation No. 2009-0002 Revision 0 Page 49 of 83 8.2 Device Uncertainty Summary 8.2.1 Sensor Uncertainties Table 8.2.1, Sensor Uncertainties 8.2.2 Power Range Drawer Uncertainties Table 8.2.2, Power Range Drawer Uncertainties DVJ= 0.250 Power Range Drawer Power Supply It 0.000 8.1.14 Effect (Dp)

Power Range Drawer Temperature Effect (Dt)

0.000 8.1.15 Power Range Drawer Humidity Effect (Dh)

0.000 8.1.16

Calculation No. 2009-0002 Revision 0 Page 50 of 83 8.2.3 Indicator Uncertainties Table 8.2.3, Indicator Uncertainties 8.2.4 PPCS Uncertainties Table 8.2.4, PPCS Uncertainties

Calculation No. 2009-0002 Revision 0 Page 5 1 of 83 8.2.5 Recorder Uncertainties Table 8.2.5, Recorder Uncertainties 8.2.6 Process Considerations Table 8.2.6, Process Considerations

Calculation No. 2009-0002 Revision 0 Page 52 of 83 8.3 Total Loop Errors 8.3.1 Total Trip Loop Error (TLETRIP)

Per Section 6.5, the total trip loop error is used to evaluate two different power range setpoint values. Both of these setpoints are increasing toward the process AL. Per Section 7.2, only the negative TLE is needed with separate random and bias teims. Using Eq. 7.1.2.1, Substituting from Section 8.2, Per Section 8.2, there are no bias uncertainties. Therefore, TLETNP-~~~ =~ 0.000%

- span 8.3.2 Total Indication Loop Error (TLEIND)

Per Section 7.1.1, the indicator loop is calculated as a 75/75 value. Therefore, the random and bias parts are determined separately for conversion from 95/95.

Substituting from Section 8.2,

Calculation No. 2009-0002 Revision 0 Page 53 of 83 TLEt~~-rdrn = =t6.438% span (95195)

Per Section 8.2, there are no bias uncertainties. Therefore, TLE~h'~-bias = 0.000% span Convert to 75/75 error:

= (1.1511.96)

e 1 ~ o r ~ ~ , ~ ~ (Section 3.3.3.13 of Ref. G.l)

= (1.1511.96) * $6.438 % span= f3.777 % span T L E I ~=DIf: 3.777 % span (75175)

Convesting to process units, T L E I N=~( f 3.777% span) * (120% RTP)/100% span T L E I N ~f=4.532% RTP (75175) 8.3.3 Total PPCS Loop Error (TLEppcs)

Per Section 7.1.1, the PPCS total loop error is calculated as a 75/75 value.

Therefore, the random and bias parts are detennined separately for conversion from 95/95.

Substituting from Section 8.2,

Calculation No. 2009-0002 Revision 0 Page 54 of 83 TLEppCS-r,jm = f 6.342% span (95195)

Per Section 8.2, there are no bias uncertainties. Therefore, TLEppCS-bias = 0.000% span Convert to 75/75 error:

= (1.1511.96)

error95i95 error75/75 (Section 3.3.3.13 of Ref. G.l)

TLEppCs= (1.1511.96) * +6.342 % span = 13.721 % span TLEPPCS = + 3.721 % span (75175)

Converting to process units, TLEPPCS = (f3.721% span) * (120% RTP)/100% span TLEPPCS =k 4.465% RTP (75175) 8.3.4 Total Recorder Loop Error (TLEREC)

Per Section 7.1.1, the recorder total loop ei+sor is calculated as a 75/75 value.

Therefore, the random and bias parts are detei~ninedseparately for conversion from 95/95.

s a 2 + D a 2 + ~ a +' s d 2 + D d 2 + R d 2

+ s m 2 + ~ r n +, ~~ t n '+ s v 2 + D V +~ ~

TLEREc-rdm =f RV' + s p 2 + D ~ ~ ++s t 2R + ~ ~ ~ t ~ f

~ t +' s h 2 + D h 2 + R h 2 + s r 2 + D r 2 +

,Rr2 + s s 2 + D s 2 + R s 2 + b e a d 2 +PE' Substituting from Section 8.2,

Calculation No. 2009-0002 Revision 0 Page 55 of 83 TLE~~c-rdrn = i 6.633% spa11 (95195)

Per Section 8.2, there are no bias uncertainties. Therefore, TLE~~c-bias = 0.000% span Convert to 75175 error:

e 1 - r 0 r ~=

~ ,(1.1511.96)

~~

err0r9~i~~ (Section 3.3.3.13 of Ref. G.l)

TLEREC = (1.1511.96)

t-6.633 % span = k3.892 % span TLEREC = f 3.892 % span (75175)

Converting to process units, TLEREC = (-t3.892% span) * (120% RTP)/100% span TLEKEC = +_ 4.670% RTP (75175)

Calculation No. 2009-0002 Revision 0 Page 56 of 83 8.4 Setpoint Evaluations 8.4.1 Power Range High Range High Flux Reactor Trip Setpoint Evaluation - Current Power Level For an increasing setpoint towards the Analytical Limit, Eq. 7.2-1 is used.

Where, AL = 118% RTP Section 6.5 TLETRIP.rdi = -6.342% span Section 8.3.1 TLETRIP.bias- = 0.000% span Section 8.3.1 PS = 120% RTP Substituting, LTSPHR=118% RTP + [(0.839)" -6.342% span+ 0.000% span]*120% RTP LTSPHR = 111.61% RTP (95195)

The margin between LTSP and FTSP is calculated in accordance with Section 3.3.8.5 of Reference G.1:

Margin = LTSP - FTSP where, LTSP = 111.61% RTP FTSP = 107% RTP Section 6.5 Substituting, Margin = 111.61% RTP - 107% RTP Margin = 4.61% RTP 8.4.2 Power Range High Range High Flux Reactor Trip Setpoint Evaluation - EPU For an increasing setpoint towards the Analytical Limit, Eq. 7.2-1 is used.

Where, ALEPU = 116% RTP Section 6.5 TLETRIP.rdi= -6.342% span Section 8.3.1 T L E T R I P - ~=~ ~0.000%

~- span Section 8.3.1 PS = 120% RTP

Calculation No. 2009-0002 Revision 0 Page 57 of 83 Substituting, LTSPHR=116% RTP + I(O.839)" -6.342% span+ 0.000% spar]*l20% RTP LTSPHR = 109.61% RTP (95195)

The margin between LTSP and FTSP is calculated in accordance with Section 3.3.8.5 of Reference G.l:

Margin = LTSP - FTSP where, LTSP = 109.61% RTP FTSP = 107% RTP Section 6.5 Substituting, Margin = 109.61% RTP - 107% RTP Margin = 2.61% RTP 8.4.3 Power Range Low Range High Flux Reactor Trip Setpoint Evaluation For an increasing setpoint towards the Analytical Limit, Eq. 7.2-1 is used.

Where, AL = 35% RTP Section 6.5 TLETRIP-rdi = -6.342% span Section 8.3.1 TLETRIP-bias- = 0.000% span Section 8.3.1 PS = 120% RTP Substituting, LTSPLR=35% RTP + [(0.839)* -6.342% span+ 0.000% span]*120% RTP LTSPLR = 28.61% RTP (95195)

The margin between LTSP and FTSP is calculated in accordance with Section 3.3.8.5 of Reference G.l:

Margin = LTSP - FTSP where, LTSP = 28.61%RTP FTSP = 20%RTP Section 6.5 Substituting,

Calculation No. 2009-0002 Revision 0 Page 58 of 83 Margin = 28.6 1% RTP - 20% RTP Margin = 8.61% RTP 8.4.4 Permissive Setpoint Evaluation Cul~entPower Level Per Attachment C, the pelmissive setpoints do not require uncertainties to be applied because per~nissivesetpoints are nominal values. Only the unblock function of each pelmissive pefforms the safety function of removing an operational bypass (block) automatically at a predetermined power level.

Attachment C recommends that pelmissive field setpoints for the pennissive unblock and block functions should be changed as follows:

Recommended Recommended Recormnended Permissive *lock (reset) Allowable Unblock FTSP I

FTSP Value P-7 9% /, RTP lo%? RTP / 5 13%

P-8 1 49% J R T P 1 50%? RTP 1 553% 1 P-9 49% /, RTP 50%? RTP 5 53%

P-10 1o%?' RTP 9% /, RTP > 6%

Per Attachment C, for each permissive there should be a 1% RTP deadband established between the permissive unblock setpoint and the block (reset) value.

Therefore, the reset for P-7, P-8, and P-9 should be 1% below the setpoint while the reset (block) for the P-10 permissive should be 1% above the setpoint.

It should be noted that the P-10 unblock setpoint allows for margin between the lower range limit of the span (0% RTP) as the enor with uncertainties is less than 9% (Section 8.3.1). In other words, no operability issues will result because FTSPp.lo- TLEWLA > 0% RTP.

Recommended Technical Specification Allowable Values for the above permissive FTSPs are established 3% from the FTSP in the direction of the unblock function (because unblocking is the safety-related protection function of the permissive). Establishing 3% margin between the FTSP and the Allowable Value is based on conservatively rounding down (to a whole number) the Operability Limit uncertainty (3.1 1% span x 120% RTP = 3.73% RTP) determined in Section 8.5 for the power range reactor trip functions.

Changes required for Extended Power Uprate (EPU)

Pex Attachment C, the P-8 and P-9 setpoints need to be revised for EPU based on Westinghouse calculations CN-TA-08-52 Rev 0 [Reference C.51 and CN-CPS-08-20 Rev 0 [Reference C.41, respectively. The changes are sulmnarized below:

Calculation No. 2009-0002 Revision 0 Page 59 of 83 For EPU, the P-8 setpoint needs to be lowered from the cussent -50% to protect the reactor during a partial loss of flow event. Reference C.5 requires that the P-8 setpoint limit reactor power to 45% when the P-8 pei~nissive block is in effect. Based on a 10% instrument uncertainty assumed in Reference C.5, Westinghouse recolnlnended the P-8 field setpoint be lowered to 35% RTP. To show that 10% uncertainty is a conservative assumption for P-8, Section 8.4 determines the uncertainty for reactor trip functions to be less than 7%. This uncertainty is also applicable to power range permissive functions that are approached from a single direction. Because the P-8 uncertainty is less than the 10% uncertainty assumed in Reference C.5, a P-8 field setpoint of 35% will be conservative.

Changing the P-8 Permissive FTSP to 35% RTP will also require changing the Technical Specification 3.3.1 Allowable Value from its present I 50%

value. A new P-8 Allowable Value can be determined by adding the 3.5%

Operability Limit uncertainty determined in Section 8.5 below for the reactor trip functions to the 35% FTSP. For conservatism, the resulting 38.5% RTP is then rounded down to an even 38% to establish a P-8 Allowable Value for EPU conditions.

e P-9 Pelmissive For EPU, the P-9 setpoint needs to change fsom a single value to a multiple setpoint tied to operation at different ranges of T,,,,. Specifically, for T,,,

operation between 558°F and 572"F, page 9 of Reference C.4 requires that the P-9 pelmissive setpoint be 35%. For T,,, operation between 572°F to 577"F, a P-8 setpoint of 50% is acceptable. Finally, for an End-of-Cycle (EOC) T,,,/power coastdown maneuver, a P-8 setpoint of 50% is acceptable over the full Tar,range of 558°F to 577°F.

The revised P-9 permissive setpoints are nominal values that do not require applying instrument uncertainty. The reason for this is that P-9 is a pennissive for a backup kip function (reactor trip on turbine trip) that is not credited in any accident analysis [Reference G.401. As such, there is no "analytical limit" in an analysis that is being protected by use of the P-9 block, and a failure of the permissive will not impact any analysis. Without an analytical limit, there is no value against which to apply instrument uncertainty. For this reason, the following nominal field trip setpoints will be used for P-9 for EPU:

35% RTP for 558°F 5 Full Load T,,, < 572°F 50% RTP for 572°F 5 Full Load T,,, I 577°F Changing the P-9 Permissive FTSP to these values will also require changing the Technical Specification 3.3.1 Allowable Value from its present 5 50%

value. A new P-9 Allowable VaIues can be determined by adding the 3.5%

Operability Limit uncertainty determined in Section 8.5 below for the reactor trip functions to the two new FTSPs. For conservatism, the resulting values

Calculation No. 2009-0002 Revision 0 Page 60 of 83 of 38.5% RTP and 53.5% RTP are rounded down to an even 38% and 53%

to establish P-9 Allowable Values for both T,,,, bands under EPU conditions.

8.4.5 Rod Withdrawal Stop Attachment C discussed the Rod Withdrawal Stop setpoint. Per Attachment C, the existing setpoint is acceptable and is stated below.

FTSPRWS = 105% RTP 8.4.6 Dropped Rod Alarm Setpoint Evaluation Attachment C discussed the Rod Drop Alarm setpoint. Per Attachment C, the existing setpoint is acceptable and is stated below.

FTSPDRA = Decreasing 2.5% RTP I 5 sec.

8.4.7 Loss of Detector Voltage Alarm Attachment C discussed the Loss of Detector Voltage Alacm setpoint. Per Attachment C, the existing setpoint is acceptable and is stated below.

FTSPEVA = 50 Vdc below Operating Voltage 8.5 Operability Limit Determination This section detesmines Operability Limits for both high neutron flux reactor trip functions. Operability Limits are established for the as-found value of the trip bistable during the Tech Spec Channel Operational Test (COT) surveillance, to deteilnine if the channel portion measured during the COT is operating within its 3-sigma drift limits.

Two Operability Limits are determined for each trip function, one on each side of the FTSP.

Per Section 7.1.5, the OL on each side of the FTSP is calculated by applying the square-root-sum-of-the-squares combination of As-Left tolerance and 30 rack drift to the FTSP.

8.5.1 High Range - High Flux Reactor Trip Operability Limit - Current Power Level Using Equation 7.1.5-3 to detem~inethe COT 30 drift value, Rd3B= (1.5) Rd2, (Eq. 7.1.5-3)

Rd3, = (1.5) 2.0 % span (Dd?, from Section 8.1.1 1)

Rd3, = Li. 3.0 % span The FTSP for the high range - high flux trip of 107% (Section 6.5), expressed as percent span, is:

Calculation No. 2009-0002 Revision 0 Page 61 of 83 FTSP = 107 + 120% = 89.16 % span Using Equation 7.1.5-1, the OLf is deteimined as:

OL' = FTSP + [RAL' + ~d,:]" (Eq. 7.1.5-1)

OL' = 89.16 % + (0.833' + 3.0')" (RAL is Dv' froin Section 8.1.13)

OL' = 89.16 % + 3.11 OL' = 92.27 % span Expressed in % RTP, OLf = (0.9227

120%) = 110.72%

For readability in the calibration procedures, the OL' is conservatively rounded down to the nearest whole percent. Therefore, OL' = 110%.

Using Equation 7.1 5 2 , the OL' is determined as:

oL- = FTSP - [RAL' + ~d321" (Eq. 7.1.5-2)

OL- = 89.16 % - (0.833' + 3.0')"

OL- = 89.16 % - 3.11 OL- = 86.05 % span Expressed in % RTP, OL- = (0.8605 " 120%) = 103.26%

For readability in the calibration procedures, the OL' is conservatively rounded up to the nearest whole percent. Therefore, OL- = 104%.

Because the High Range - High Flux Reactor Trip is an increasing trip, the OL' value of 110% should be the limit coinpared to the COT as-found value to determine Technical Specification operability of the channel. However, an as-found value outside either the OL' or OL- indicates that the channel is operating abnormally.

From Section 8.4.1, the Limiting Trip Setpoint for the High Range - High Flux Reactor Trip is 111.63% RTP. For this increasing trip, the OL' value of 110%

is more conservative (i.e., restrictive) than the LTSP. Per Section 2.2, with margin between the OL' value and the LTSP, the OL' value is acceptable to use for channel operability deteimination during COT.

8.5.2 Low Range - High Flux Reactor Trip Operability Limit Using Equation 7.1.5-3 to deteilnine the COT 30 drift value, (Eq. 7.1.5-3)

(Dd2, from Section 8.1.1 1)

The FTSP for the low range - high flux trip of 20% (Section 6.5), expressed as percent span, is:

FTSP = 20 + 120% = 16.67 % span

Calculation No. 2009-0002 Revision 0 Page 62 of 83 Using Equation 7.1.5- 1, the OL' is deteimined as:

OL' = FTSP + [RAL' + ~d~:]" (Eq. 7.1.5-1)

OL' = 16.67 % + (0.833~+ 3.0~)" (RAL is Dv2 fronl Section 8.1.13)

OL' = 16.67 % + 3.11 OLf = 19.78 %span Expressed in % RTP, OL' = (0.1978

120%) = 23.74%

For readability in the calibration procedures, the OL' is conservatively rounded down to the nearest whole percent. Therefore, OL' = 23%.

Using Equation 7.1.5-2, the OL- is determined as:

OL- = FTSP - [RAL~+ ~d3,2]" (Eq. 7.1.5-2)

OL' = 16.67 % - (0.833~+ 3.0~)"

OL- = 16.67 % - 3.11 OL- = 13.56 %span Expressed in % RTP, OL' = (0.1356

120%) = 16.27%

For readability in the calibration procedures, the OL- is conservatively rounded up to the nearest whole percent. Therefore, OL- = 17%.

Because the Low Range -High Flux Reactor Trip is an increasing trip, the OLC value of 23% should be the limit compared to the COT as-found value to deteilnine Technical Specification operability of the channel. However, an as-found value outside either the OL' or OL- indicates that the channel is operating abnormally.

From Section 8.4.3, the Limiting Trip Setpoint for the Low Range -High Flux Reactor Trip is 28.63% RTP. For this increasing trip, the OL' value of 23% is more conservative (i.e., restrictive) than the LTSP. Per Section 2.2, with margin between the OL' value and the LTSP, the OL+ value is acceptable to use for channel operability detel-mination during COT.

8.5.3 Permissive Operability Limits Separate calculations are not performed for the Operability Limits for the four permissive FTSPs discussed in Section 8.4.4 above. The &3% RTP margin on each side of the FTSP established above for the high range and low range high flux reactor trip OLs is also applicable to the permissives. For each permissive, the OL' will be set 3% RTP above the FTSP, and the OL- will be set 3% RTP below the FTSP, as shown in the following table and in Attachment B:

Calculation No. 2009-0002 Revision 0 Page 63 of 83 8.6 Acceptable As-Left and As-Found Calibration Tolerances 8.6.1 Acceptable As-Found Calibration Tolerances 8.6.1.1 Power Range Drawer As-Found Tolerance (DAF1,DAF2, DAF3)

Using Eq. 7.1.3.1 to determine the As-Found tolerance for indication, where:

Dv~ = k0.4 17 % Span Section 8.1.13 Dd = k2.000 % Span Section 8.1.1 1 Dinl = 10.596 % Span Section 8.1.12 DMl = 3~2.128% Span Collverting to calibration units and rounding to procedure precision,

Calculation No. 2009-0002 Revision 0 Page 64 of 83 DM, = 12.128 % span * (120% RTP/100% span)

DAF, =12.554%RTP Per References P.20 - P.27, the power range drawers are calibrated using the calibration module input and reading the output on the local analog indicator. Per Section 3.3.5.3 of Reference G. 1, the readability of an analog instrument is !h the smallest division.

Reference G.29 shows that each division represents 1% RTP.

Conservatively rounding for procedure precision, DAFl = 2.0% RTP Using Eq. 7.1.3.1 to detel~ninethe As-Found tolerance for trips, where:

Dv2 = 10.833 % Span Section 8.1.13 Dd = 12.000 % Span Section 8.1.11 Dmt = 10.596 % Span Section 8.1.12 DM2 = .t2.247 % Span Converting to calibration units and rounding to procedure precision, DMz = 3=2.247%span * (120% RTP/100% span)

DM2 = %2.696%RTP Conservatively rounding to procedure precision, DAF, = 2.0% RTP Using Eq. 7.1.3.1 to determine the As-Found tolerance for calibration, where:

Dv3 = 10.250 % Span Section 8.1.13 Dd = 12.000 % Span Section 8.1.1 1 Dm2 = 10.563 % Span Section 8.1.12

Calculation No. 2009-0002 Revision 0 Page 65 of 83 DAF, = It2.093 % Span Converting to calibration units and rounding to procedure precision, DAF3 = Zt2.093% span * (10.000 Vdc/100% span)

DAF, = Zt0.209 Vdc Therefore, 8.6.1.2 Indicator As-Found Tolerance (IAF)

Using Eq. 7.1.3.2, Where:

Iv =& 0.833% span Section 8.1.22 Id = Zt 1.028% span Section 8.1.20 Iln = h 0.000% span Section 8.1.21 IM = Zt 1.323% span Converting to calibration units and rounding to procedure precision, IAF =& 1.323% span * (120% RTP/100% span)

IAF = It 1.588% RTP Per Section 3.3.5.3 of Reference G. 1, the readability of an analog instrument is % the smallest division. Reference G.29 shows that each division represents 2% RTP. Therefore, the As-Found Tolerance must be conservatively rounded to 1.O% RTP. As a result, IAF =

1.0% RTP

Calculation No. 2009-0002 Revision 0 Page 66 of 83 8.6.1.3 PPCS As-Found Tolerance (PPCSAF)

Using Eq. 7.1.3.3, Where:

PPCSv = h 0.500% span Section 8.1.32 PPCSd = h 0.000% span Section 8.1.30 PPCSm =

0.047% span Section 8.1.31 PPCSAF = h 0.502% span Converting to calibration units and rounding to procedure precision, PPCSAF =

0.502% span * (120% RTP/100% span)

PPCSAF = & 0.6% RTP 8.6.1.4 Recorder As-Found Tolerance (RAF)

Using Eq. 7.1.3.4, Where:

Rv = h 2.000% span Section 8.1.42 Rd = h 0.250% span Section 8.1.40 Rm = h 0.047% span Section 8.1.41 RAF =*2.016%spail Converting to calibration units and rounding to procedure precision, RAF =

2.016% span * (50 mVdc/100% span)

RAF =& 1.01 mVdc

Calculation No. 2009-0002 Revision 0 Page 67 of 83 8.6.2 Acceptable As-Left Calibration Tolerances 8.6.2.1 Power Range Drawer As-Left Tolerances (DAL,, DAL2)

Using Eq. 7.1.4.1, the Acceptable As-Left Tolerance for the Power Range Drawer for indication is, DALI = + D v l DAL1 = h 0.417% span Section 8.1.13 Converting to calibration units and rounding to procedure precision, DALl =

0.417% span * (120% RTP/100% span)

DAL1 = & 0.5% RTP Using Eq. 7.1.4.1, the Acceptable As-Left Tolerance for the Power Range Drawer for trips is, DAL2 = i D v z DALz = h 0.833% span Section 8.1.13 Converting to calibration units and rounding to procedure precision, DALz =

0.833% span * (120% RTP/100% span)

DALz = & 1.0% RTP Pelmissive setpoints are an exception to this i 1.O% as-left tolerance for trip setpoints. A 1% deadband is established in the calibration procedure between permissive [unbloclc] setpoints and their associated reset [bloclc] setpoints. For the three permissive setpoints that restore protective functions on increasing signal (P-7, P-8, and P-9), the unbloclc setting that clears the permissive is established 1%

above the setting that bloclcs the trips. The as-left tolerance for the unblock setting is the 1% margin between the two setpoints; i.e., the unblock setting +0, -1 percent RTP. The corresponding as-left tolerance for the block setting is established by the 1% band below the block setting; i.e., the block setting +0, -1 percent RTP.

The P-10 permissive shares the same trip bistable with the P-7 pelmissive, such that the P-10 unblock is the P-7 block function, and the P-10 block is the P-7 unblock function. The as-left tolerances for the P-10 block and unbloclc are therefore the same as the P-7 unbloclc and block as-left tolerances, respectively.

Using Eq. 7.1.4.1, the Acceptable As-Left Tolerance for the Power Range Drawer for calibration is,

Calculation No. 2009-0002 Revision 0 Page 68 of 83 D L 3 =h 0.250% span Section 8.1.13 Converting to calibration units and rounding to procedure precision, D L 3 =

0.250% span * (10.000 Vdc/100% span) 8.6.2.2 Indicator As-Left Tolerances (IAL)

Using Eq. 7.1.4.2, the Acceptable As-Left Tolerance for the Indicator 1%

1AL =*Iv IAL = h 0.833% span Section 8.1.22 Converting to calibration units and rounding to procedure precision, IAL =h 0.833% span * (120% RTP/100% span)

IAL =

1.0% RTP 8.6.2.3 PPCS As-Left Tolerances (PPCSAL)

Using Eq. 7.1.4.3, the Acceptable As-Left Tolerance for the PPCS is, PPCSAL = It: PPCSv PPCSAL =

0.500% span Section 8.1.32 Converting to calibration units and rounding to procedure precision, PPCSAL = & 0.500% span * (120% RTP/100% span)

PPCSAL = It 0.6% RTP 8.6.2.4 Recorder As-Left Tolerances (RAL)

Using Eq. 7.1.4.4, the Acceptable As-Left Tolerance for the Recorder is, RAL =hRALv RAL *

= 2.000% span Section 8.1.42 Converting to calibration units and rounding to procedure precision, RAL = 2.000% span * (50 mVdc/100% span)

RAL = 1 1.00 mVdc

Calculation No. 2009-0002 Revision 0 Page 69 of 83 8.7 Channel Check Tolerance (CCT)

Using Eq. 7.1.6, the Channel Check Tolerance is dete~minedas follows (at a 95/95 value):

CCT =

1

+ + 1v2+ ~ r e a ~ ) ~ ,+, ,(sa2 + Da2 + 1a2 + s d 2 + Dd2 + 1d2

+sv2 +

Substituting fronl Section 8.2, D V +~1v2 ~ +~rea~)~,,~

(0.000~+ 2.000~+ 0.000~+ 0 . 0 0 0 ~+ 2.000~+ 1.028~

+ 0.000~+ 0.417~+ 0.833~+0.000~),,, + (0.000~+

CCT =+

2.000~+ 0 . 0 0 0 ~+ 0 . 0 0 0 ~+ 2.000~+ 1.028~+ 0.000~

+ 0.417~+ 0.833~+ 0 . 0 0 0 ~ ) ~ , ~ ~

CCT = + 4.455% span Converting to process units, CCT = + 4.455% span * (120% RTP/100% span)

CCT = It 5.346% RTP (95/95)

Per Reference G.29, the control room indication for Power Range has a minor division of 2.0% RTP. Per Section 7.1.C, the CCT value should be rounded to the precision that is readable on the associated loop indicator. Per Section 3.3.5.3 of Reference G. 1, the readability of these indicators is + % the smallest division (or 1.0% RTP). Therefore, the CCT value is rounded up to the nearest 1.O% RTP interval.

CCT = i5.0% RTP (95195)

Per References G.30 and G.31, the existing CCT for Power Range is + 3.0% RTP. The existing CCT is less than the calculated CCT. Therefore per Section 2.0, the existing CCT is acceptable and may be retained.

Calculation No. 2009-0002 Revision 0 Page 70 of 83 9.0 RESULTS AND CONCLUSIONS, WITH LIMITATIONS 9.1 Total Loop Error The Total Loop Errors calculated in Sectioil8.3 are shown below:

Table 9.1, Total Loop Errors 9.2 Analytical Limits The Analytical Limits are determined by Westinghouse (Ref. G. 18 and G.40) and are summarized below:

Table 9.2, Analytical Limits Range - High Flux 9.3 Limiting Trip Setpoints, Operability Limits (OL), and Recommended Tech Spec Changes AR 89661 1 determined that the Technical Specification Allowable Values for several protection systein functions in TS 3.3.1 (WS) and TS 3.3.2 (ESFAS) were non-conservative. As a result, the I&C calibration procedures were revised to install temporary administrative limits (teimed Allowable Limits in the ICPs) on the trip bistable as-found values until a license amendment is approved to revise the TS sections.

The Limiting Trip Setpoints for primary trip functions determined in this calculation provide new Technical Specification limits (Allowable Values) for channel operability to protect the accident analyses Analytical Limits. The LTSPs also satisfy the definition of a Limiting Safety System Setting in 10CFR50.36. Backup trips and pel-tnissives do not

Calculation No. 2009-0002 Revision 0 Page 71 of 83 have a LTSP that can be used as an Allowable Value in Tech Specs because there is no analytical limit to "anchor" the LTSP. Therefore, it is recomlnended that the LTSPs for the prinlary trip functions on high flux be included in a license amendment to revise RPS TS 3.3.1, Table 3.3.1-1 Allowable Values.

Operability Limits have been determined for the reactor trip functions and permissive unblock functions. The OLs provide new limits to be applied in the I&C calibration procedures for establishing Technical Specification operability of the channels during Channel Operational Testing (COT).

It is recommended that the Operability Limits be included in the Technical Requirements Manual (TRM) as limits (more restrictive than the LTSPs) for establishing channel operability during channel surveillance testing. The reason for including OLs in the TRM rather than the Technical Specifications is to allow the station flexibility to revise the field setpoint values, along with their as-left, as-found, and OL values, without requiring prior NRC approval. The LTSPs, which provide protection for the accident analyses as Limiting Safety System Settings, are the appropriate Allowable Values for the protection functions in the Specifications and would remain bounding limits for the primary trips (only).

The following Operability Liinits are proposed to be added to the rack calibration procedures, as shown in the procedure markups in Attachment B.

Table 9.3-1 Operability Limits L- 32% RTP

Calculation No. 2009-0002 Revision 0 Page 72 of 83 9.4 Setpoint Evaluation This calculation has determined Limiting Trip Setpoints for the priinary reactor trip setpoints for High Range and Low Range High Flux for the current power level and also for the Extended Power Uprate (EPU) condition. These new LTSPs are based on the Analytical Limits summarized in 9.2 above.

As discussed in Section 9.3 above, it is recommended that the LTSPs listed in Table 9.4-1 below for the current power level be included as new Allowable Values in TS Table 3.3.1- 1 by submittal of a license ainendinent request (LAR). It is also recomnended that the separate EPU license amendment request revise the Allowable Value to the value shown below for the High Range - High Flux trip, due to the change in Analytical Limit from 118% to 116% for EPU.

Table 9.4.1, Trip Setpoints Per Section 8.4.3, it is reconmended that the permissive setpoints be changed as follows:

Table 9.4.2, Permissive Setpoints

Calculation No. 2009-0002 Revision 0 Page 73 of 83 Allowable Value Per Section 8.4, the alarm setpoints are acceptable and are summarized below.

Table 9.4.3, Alarm Setpoints 9.5 Acceptable As-Left and As-Found Tolerances This calculation has determined the Acceptable As-Found and As-Left Tolerances for the calibrated instruments listed in Table 1.5-1 (sensors are not calibrated). The calibration procedures listed in Section 10 should be revised as appropriate.

Table 9.5, As-Left and As-Found Tolerances

Calculation No. 2009-0002 Revision 0 Page 74 of 83 9.6 Channel Check Tolerance The Channel Check Tolerance for the control board indicators is suimnarized below. The existing CCT value is more restrictive than the calculated CCT. Therefore, the existing CCT is acceptable and Inay be retained.

Table 9.6-1, Channel Check Tolerance 9.7 Limitations 9.7.1 Temperature Limitations The results of this calculation are valid only if the temperature inside the ControVComputer Room instrumentation panels does not exceed 120°F. GAR 0103 1654 has been generated to track this limitation.

9.7.2 Implementation Limitation Changes recommended by this calculation are NOT to be i~nplementedwithout approval of the PBNP Design Authority or the appointed designee.

Calculation No. 2009-0002 Revision 0 Page 75 of 83 9.8 Graphical Representation of Setpoints Figure 9.8.1, High Range - High Flux Reactor Trip Setpoint for Current Power Level Allalytical Limit LTSP 1 -

118%RTP lll.6l%RTP Allowable Value (proposed) 111%RTP As-Left + 108% RTP FTSP 7- 107% RTP As-Left - 106% RTP As-Found - 105% RTP

Calculation No. 2009-0002 Revisio~l0 Page 76 of 83 Figure 9.8.2, High Range - High Flux Reactor Trip Setpoint for Extended Power Uprate Analytical Limit 116% RTP Allowable Value (proposed) 109% RTP OL + and As-Found +

As-Left + 108% RTP FTSP 7 107%RTP As-Left - 106% RTP As-Found - 105% RTP 7-104% RTP OL-

Calculation No. 2009-0002 Revision 0 Page 77 of 83 Figure 9.8.3, Low Range - High Flux Reactor Trip Setpoint Analytical Lullit

---t- """'

I 28.61% RTP Allowable Value (proposed) 28% RTP LTsp As-Found + 22% RTP As-Left + 21% RTP As-Left - 19% RTP As-Found - 18% RTP

Calculation No. 2009-0002 Revision 0 Page 78 of 83 Figure 9.8.4, Proposed Settings for P-7 and P-10 Permissives Proposed P-7 Utlblock 13% RTP Allowable Value and OL +

As-Found + 12% RTP FTSP and As-Left + 10% RTP As-Left - 9% RTP As-Found - 8% RTP OL - 7% RTP OL + 12% RTP As-Found + 11% RTP FTSP and As-Left + 9% RTP As-Left - 8% RTP As-Found - 7% RTP Proposed P- 10 Utlblock Allowable Value and OL - 6% RTP

Calculation No. 2009-0002 Revision 0 Page 79 of 83 Figure 9.8.5, Proposed Settings for P-8 Permissive

@ Current Power Level A

Proposed P-8 Unblock 53% RTP Allowable Value and OL +

As-Found + 52% RTP FTSP and As-Left + 50% RTP As-Left - 49% RTP As-Found - 48% RTP OL - 47% RTP

@ Extended Uprate Power A

Proposed P-8 Unblock AUowable Value and OL + 38% RTP As-Found + 37% RTP FTSP and As-Left + 35% RTP As-Left - 34% RTP As-Found - 33% RTP OL - 32% RTP

Calculation No. 2009-0002 Revision 0 Page 80 of 83 Figure 9.8.6, Proposed Settings for P-9 Permissive

@ Current Power Level Proposed P-9 Unblock 53% RTP Allowable Value and OL +

FTSP and As-Left + 50% RTP As-Left - 49% RTP As-Found - 48% RTP OL - 47% RTP

@ Extended Uprate Power Proposed P-9 Unblock Proposed P-9 Unblock Allowable Valuc and OL + 38% RTP Allowable Value and OL + 53% RTP As-Found + 37% RTP As-Found + 52% RTP FTSP and As-Left +

As-Left -

As-Found -

i i FTSP and As-Left +

As-Li:

As-Found -

50% RTP 49% RTP 48% RTP OL - 32% RTP 47% RTP For Tavg < 572 F For Tavg 2 572 F

Calculation No. 2009-0002 Revision 0 Page 8 1 of 83 10.0 IMPACT ON PLANT DOCUMENTS

[NOTE: Passport Engineering Change (EC) Number for Calculation 2009-0002 is 13195.]

Q Setpoint Document, STPT 1.1, Rev. 3, "Reactor Trip NIS, Unit 1" Low Range -High Flux and High Range - High Flux setpoints should be changed per Section 9.4.

Q Setpoint Document, STPT 1.1, Rev. 4, "Reactor Trip NIS, Unit 2" Low Range -High Flux and High Range - High Flux setpoints should be changed per Section 9.4.

Setpoint Document, STPT 3.1, Rev. 11, "P6, P7, P8, P9, and P10" Permissive Allowable Values and setpoints for P7 - PI0 should be changed per Sections 9.3 and 9.4.

Q Setpoint Document, STPT 4.1, Rev. 8, "Rod Stop and Turbine Runback Setpoints: Rod Stops" Per Section 6.5, no changes are required for the Rod Withdrawal Stop setpoint.

e lICP 02.007, "Nuclear Instrumentation Power Range Channels 92 Day Channel Operational Test" Rev. 10 New As-Found Tolerances for the Low Range - High Flux, High Range - High Flux, and Rod Stop bistables for loops N-41 though N-44 need to be incorporated. Also, new allowable values and setpoints need to be incosporated for the Low Range -High Flux and High Range - High Flux bistables.

e 2ICP 02.007, "Nuclear Instrumentation Power Range Channels 92 Day Channel Operational Test" Rev. 12 New As-Found Tolerances for the Low Range - High Flux, High Range - High Flux, and Rod Stop bistables for loops N-41 through N-44 need to be incolporated. Also, new allowable values and setpoints need to be incorporated for the Low Range -High Flux and High Range - High Flux bistables.

e lICP 02.022, "Nuclear Instrulnentation System Power Range Channels Shutdown operational Test" Rev. 8 New setpoints and allowable values for pennissives P7 - PI0 need to be incorporated. In addition, As-FoundlAs-Left Tolerances for permissive P7 - P10, Low Range - High Flux, High Range - High Flux, and Rod Stop bistables for loops N N-44 need to be incorporated.

e 21CP 02.022, "Nuclear Instru~nentationSystem Power Range Channels Shutdown operational Test" Rev. 7 New setpoints and allowable values for permissives P7 - P10 need to be incosporated. In addition, As-FoundlAs-Left Tolerances for permissive P7 - P10, Low Range - High Flux, High Range - High Flux, and Rod Stop bistables for loops N N-44 need to be incorporated.

Calculation No. 2009-0002 Revision 0 Page 82 of 83 lICP 04.026RD, "Nuclear Instrumentation Power Range Red Channel N41 Outage Calibration and ECAD Testing.

New As-Found Tolerances for the Power Range Drawer (NM3 lo), Recorder, Control Room Indicator, and PPCS for loop N-41 need to be incorporated.

IICP 04.026WH, "Nuclear Instrumentation Power Range White Channel N42 Outage Calibration and ECAD Testing.

New As-Found Tolerances for the Power Range Drawer (NM3 lo), Recorder, Control Room Indicator, and PPCS for loop N-42 need to be incorporated.

lICP 04.026BL, "Nuclear Instrumentation Power Range Blue Channel N43 Outage Calibration and ECAD Testing.

New As-Found Tolerances for the Power Range Drawer (NM3 lo), Recorder, Control Room Indicator, and PPCS for loop N-43 need to be incorporated.

lICP 04.026YL, "Nuclear Instrumentation Power Range Yellow Channel N44 Outage Calibration and ECAD Testing.

New As-Found Tolerances for the Power Range Drawer (NM3 lo), Recorder, Control Room Indicator, and PPCS for loop N-44 need to be incorporated.

21CP 04.026RD, "Nuclear Instrumentation Power Range Red Channel N41 Outage Calibration and ECAD Testing.

New As-Found Tolerances for the Power Range Drawer (NM3 1O), Recorder, Control Room Indicator, and PPCS for loop N-41 need to be incorporated.

21CP 04.026WH, "Nuclear Instrumentation Power Range White Channel N42 Outage Calibration and ECAD Testing.

New As-Found Tolerances for the Power Range Drawer (NM3 lo), Recorder, Control Room Indicator, and PPCS for loop N-42 need to be incorporated.

2ICP 04.026BL, "Nuclear Instrumentation Power Range Blue Channel N43 Outage Calibration and ECAD Testing.

New As-Found Tolerances for the Power Range Drawer (NM310), Recorder, Control Room Indicator, and PPCS for loop N-43 need to be incorporated.

2ICP 04.026YL, "Nuclear Instlumentation Power Range Yellow Channel N44 Outage Calibration and ECAD Testing.

New As-Found Tolerances for the Power Range Drawer (NM3 lo), Recorder, Control Room Indicator, and PPCS for loop N-44 need to be incorporated.

Technical Specification 3.3.1 "Reactor Protection System (RPS) Instrumentation" Amendment 201 (Unit 1) and 206 (Unit 2)

New Allowable Values for Low Range - High Flux, High Range - High Flux, and permissives P-7, P-8, P-9, and P-10 have been detennined in this calculation and should be incorporated accordingly.

Calculation No. 2009-0002 Revision 0 Page 83 of 83 11.0 ATTACHMENT LIST Attachment A Walkdown for PBNP-IC-38 (12 pages)

Attachment B Instrument Scaling Changes for Calibration Procedures 1(2)ICP 02.007, l(2)ICP 02.022, 1(2)1CP 04.026RD, l(2) 04.026WH, l(2)ICP 04.026BL, and l(2)ICP 04.026YL (18 pages)

Attachment C Process and Environmental Considerations (9 pages)

Attachment D DIT CRR-I&C-012 "Treatment of Backup Trips and Permissives" Issued 6/4/07 (5 pages)

Attachment E Westinghouse letter RRS-VICO-02-689, "NIS Analog Meters", dated 12/4/02 (5 pages) 12.0 10 CFR 50.59 REVIEW 10 CFR 50.59 screening SCR 2007-0078-00 was prepared to support implementing the limits determined by this calculation into the associated calibration procedures. The screening concluded that a 50.59 evaluation and UFSAR change are not required as a result of the addition of calibration limits listed in Section 9.7 above.

NRC prior approval of a licensing amendment is required in order to implement the revised values in the Technical Specifications for the RPS Allowable values associated wit11 the reactor trip and permissive functions determined in this calculation. The purpose of a 50.59 review is to determine if prior NRC approval is necessary to implement changes to the plant. No 50.59 review is necessary for revising the Technical Specification values because prior NRC approval through a license amendment is already acknowledged to be necessaly. The present intent is to include the TS changes identified as EPU changes in this calculation for RPS and ESFAS setpoints in the Extended Power Uprate License Amendment Request.

Note that EPU implementation after the EPU license amendment is received from NRC will require separate screening and possibly full 50.59 evaluation of individual changes being made.

For future EPU implementation, a separate 50.59 screening number (SCR 2008-178) and a separate 50.59 evaluation number (SE 2008-014) have been reserved.

Calculation No. 2009-0002 Revision 0 Page A1 of A12 blfekrlarm Locatiaa [BldplEievr"iocn;!~l~r~~:~ iines]

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Calculation No. 2009-0002 Revision 0 Page A2 of A1 2 Attachment A

Calculation No. 2009-0002 Revision 0 Page A3 of A12 Attachment A

Calculation No. 2009-0002 Revision 0 Page A4 of A12 Attachment A l(2)N-42B - Detector A

Calculation No. 2009-0002 Revision 0 Page A5 of A12 Attachment A

Calculation No. 2009-0002 Revision 0 Page A6 of A12 Attachment A

CalculationNo. 2009-0002 Revision 0 Page A7 of A12 Attachment A l(2)N-42~

POWER RANGE A

Calculation No. 2009-0002 Revision 0 Page A8 of A12 Attachment A

/

FULL POWER

CalculationNo. 2009-0002 Revision 0 Page A9 of A12 Attachment A

Calculation No. 2009-0002 Revision 0 Page A10 of A12 Attachment A

Calculation No. 2009-0002 Revision 0 Page A1 1 of A12 Attachment A

Calculation No. 2009-0002 Revisiol~0 Page A12 of A12 Attachment A

Calculation No. 2009-0002 Revision 0 Page B l of B18 Attachment B This calculation has determined Acceptable As-Found Tolerance values for all instrulnents identified in Section 1.5. In addition, new Operability Limits have been determined for the reactor trips during the Channel Operational Test (COT). The following tables provide changes to calibration procedures P.3, P.5, and P.20 -

P.27. The shaded boxes represent the changes; other fields are shown for convenience.

l(2) ICP 02.007 Series - Current Power Level New limits for N-41 Red Channel I, N-42 White Channel 11, N-43 Blue Channel 111, and N-44 Yellow Channel IV OUTPUT LIMITS Bistable NC305 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance &-Left Tolerallce Operability Limits Overpower Low 20.0 ? 18.0 22.0 19.0 21.0 17.0 23.0 Setpoint Trip 0 TECHNICAL SPECIFICATION LIMIT 5 28%

OUTPUT LIMITS Bistable NC305 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Reset 18.0 4 16.0 20.0 17.0 19.0 OUTPUT LIMITS Bistable NC302 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Toleralice

% % % % yo Overpower Rod Stop 105.0 ? 103.0 107.0 104.0 106.0 OUTPUT LIMITS I

Bistable NC302 I AS-LEFT I As-Found Tolerance 1 As-Left Tolerance Reset 103.0 4 101.0 105.0 102.0 104.0 OUTPUT LIMITS Bistable NC306 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left ToleraIlce Operability Limits Overpower High 107.0 ? 105.0 109.0 106.0 108.0 104.0 110.0 Setpoint Trip

TECHNICAL SPECIFICATION LIMIT 5 111%

OUTPUT LIMITS Bistable NC306 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolera~lce Yo % % % %

Reset 105.0 4 103.O 107.0 104.0 106.0

Calculation No. 2009-0002 Revision 0 Page B2 o f B l 8 Attachment B l(2) ICP 02.007 Series - Extended Power Uprate Level New limits for N-41 Red Channel I, N-42 White Channel 11, N-43 Blue Channel 111, and N-44 Yellow Channel IV

/ Bistable NC305 SETPOINT OUTPUT AS-FOUND AS-LEFT As-Found Tolerance LIMITS As-Left Tolerallce Operability Limits 1

Overpower Low 20.0 -? 18.0 22.0 19.0 21.0 17.0 23.0 Setpoint Trip TECHNICAL SPECIFICATION LIMIT 5 28%

OUTPUT LIMITS Bistable NC305 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Reset 18.0 4 16.0 20.0 17.0 19.0 OUTPUT LIMITS Bistable NC302 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Overpower Rod Stop 105.0 ? 103.0 107.0 104.0 106.0 OUTPUT LIMITS Bistable NC302 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Reset 103.0 4 101.0 I 105.0 102.0 104.0 OUTPUT LIMITS Bistable NC306 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance ~ ~ ~ ~ f Operability

-Tolerance t Limits I

Overpower High 107.0 1' 105.0 109.0 106.0 108.0 104.0 109.0 Setpoint Trip a TECHNICAL SPECIFICATION LIMIT 5 109%

OUTPUT LIMITS Bistable NC306 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Reset 105.0 4 103.0 107.0 104.0 106.0

Calcdation No. 2009-0002 Revision 0 Page B3 of B18 Attachment B l(2) ICP 02.022 Series - Current Power Level New limits for N-41 Red Channel I, N-42 White Channel 11, N-43 Blue Channel 111, and N-44 Yellow Channel IV Bistable OUTPUT LIMITS NC308 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Operability Liinits P-7 Unblock and P-10 Block t 8.0% 12.0% 9.0% 10.0% 7.0% 13.0%

m P-7 TECHNICAL SPECIFICATION LIMIT 5 13%

Bistable OUTPUT LIMITS NC308 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Operability Limits P-7 Block and P-10 9.0% -1 7.0% 11.0% 8.0% 9.0% 6.0% 12.0%

Unblock m P-10 TECHNICAL SPECIFICATION LIMIT 1 6%

Bistable OUTPUT LIMITS NC305 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Operability Limits Overpower Low Setpoint Trip 20.0% t 18.0% 22.0% 19.0% 21.0% 17.0% 23.0%

e TECHNICAL SPECIFICATION LIMIT 5 28%

OUTPUT LIMITS Bistable NC305 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance I

Reset 18.0% & 16.0% 20.0% 17.0% 19.0%

Bistable OUTPUT LIMITS NC303 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Operability Limits P-9 Unblock 50.0%? 48.0% 52.0% 49.0% 50.0% 47.0% 53.0%

I 0 P-9 TECHNICAL SPECIFICATION LIMIT 5 53% I Bistable OUTPUT LIMITS NC303 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-LeR Tolerance P-9 Block (reset) 49.0% 4 47.0% 51.0% 48.0% 49.0%

Calculation No. 2009-0002 Revision 0 Page B4 of B 18 Attachment B Bistable OUTPUT LIMITS NC304 SETPOINT I AS-FOUND I AS-LEFT As-Found Tolerance 1 As-Left Tolerance I Operability Limits e P-8 TECHNICAL SPECIFICATION LIMIT 5 53%

Bistable I

OUTPUT I AS-FOUND I I LIMITS

/ 1/

I NC304 I

SETPOINT I I AS-LEFT I

As-Found Tolerance I

As-Left Tolerance P-8 Block (reset) 49.0% & 47.0% 51.0% 48.0% 49.0%

OUTPUT LIMITS Bistable NC302 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance I I I ,

Overpower Rod Stop 105.0% ? 103.0% 107.0% 104.0% 106.0%

Bistable OUTPUT LIMITS NC302 AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance SETPOINT Reset 103.O% 4 101.0% 105.0% 102.0% 104.0%

Bistable OUTPUT LIMITS NC306 SETPOINT AS-FOUND LOW HIGH I I

Overpower High 107.0% ? 105.0% 109.0%

Setpoint Trip e TECHNICAL SPECIFICATION LIMIT 5 111%

Bistable OUTPUT LIMITS NC306 SETPOINT AS-LEFT LOW HIGH

Overpower High 85.0% ? 84.0% 86.0%

Setpoint Trip Reset 1 83.0% $ 1 e TECHNICAL SPECIFICATION LIMIT 5 1 1 1 %

Calculation No. 2009-0002 Revision 0 Page B.5 of B18 Attachment B l(2) ICP 02.022 Series - Extended Power Uprate Level New limits for N-41 Red Channel I, N-42 White Channel 11, N-43 Blue Channel 111, and N-44 Yellow Channel IV 7

Bistable OUTPUT LIMITS NC308 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Operability Limits P-7 Unblock and P-10.0% 1' 8.0% 12.0% 9.0% 10.0% 7.0% 13.0%

10 Block 0 P-7 TECHNICAL SPECIFICATION LlMIT 5 13%

Bistable OUTPUT LIMITS NC308 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Operability Limits P-7 Block and P-10 11.0% 6.0% 12.0%

9.0% 7.0% 8.0% 9.0%

Unblock e P-10 TECHNICAL SPECIFICATION LIMIT > 6%

Bistable OUTPUT LIMITS NC305 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolera~lce Operability Limits Overpower Low 20.0% 1' 18.0% 22.0% 19.0% 21.0% 17.0% 23.0%

Setpoint Trip a TECHNICAL SPECIFICATION LIMIT 5 28%

2 OUTPUT LIMITS Bistable NC305 SETPOINT AS-FOUND AS-LEFT As-Found Tolera~ice As-Left Tolerance Reset 18.0% -1 16.0% 20.0% 17.0% 19.0%

Bistable OUTPUT LIMITS NC303 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Operability Limits P-9 Unblock for 35.0% 38.0%

35.0%? 33.0% 37.0% 34.0% 32.0%

Tavg < 572OF P-9 Unblock for 50.0% 47.0%

50.0%1' 48.0% 52.0% 49.0% 53.0%

Tavg 2 572°F I e P-9 TECHNICAL SPECIFICATION LIMIT for Tavg < 572°F : 5 38%

I 0 P-9 TECHNICAL SPECIFICATION LIMIT for Tavg 2 572OF :5 53%

1 Bistable OUTPUT LIMITS NC303 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance P-9 Block (Tavg < 572OF) 34.0% & 32.0% 36.0% 33.0% 34.0%

I I I I I I I P-9 Block (Tavg 2 572OF) 49.0% -1 47.0% 51.0% 48.0% 49.0%

Calculation No. 2009-0002 Revision 0 Page B6 of B18 Attachment B Bistable OUTPUT LIMITS NC304 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Operability Limits P-8 Unblock 35.0% ? 33.0% 1 37.0% 34.0% 1 35.0% 32.0% 1 38.0%

I 0 P-8 TECHNICAL SPECIFICATION LIMIT 5 38% I OUTPUT LIMITS Bistable NC304 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance P-8 Block (reset) 34.0% 4 32.0% 36.0% 33.0% 34.0%

1 Bistable NC302 SETPOINT OUTPUT AS-FOUND AS-LEFT As-Found Tolerance LIMITS As-Left Tolerance Overpower Rod Stop I I

105.0%? I I I I 103.0%

t 107.0%

I 104.0%

t 106.0%

Bistable OUTPUT LIMITS NC302 SETPOINT AS-FOUND AS-LEFT As-Found Tolerance As-Left Tolerance Reset 103.0% 4 101.0% 105.0% 102.0% 104.0%

Bistable OUTPUT LIMITS NC306 SETPOINT AS-FOUND LOW HIGH

Overpower High 107.0% ?' 105.0% 109.0%

Setpoint Trip TECHNICAL SPECIFICATION LIMIT 5 109%

Bistable OUTPUT LIMITS NC306 SETPOINT AS-LEFT LOW HIGH

Overpower High Setpoint Trip I 85.0% T I I Reset 1 83.0% 4 1 1 82.0% 1 83.0% 1 I 0 TECHNICAL SPECIFICATION LIMIT 5 109% I

Calculation No. 2009-0002 Revision 0 Page B7 o f B l 8 Attachment B It is recommended that the calibratioll table for the drawer is broken into two separate tables as follows for the percent level indicator and the output from the summing amplifier.

Calculation No. 2009-0002 Revision 0 Page B8 of B18 Attachment B 1N-41 NM-3 10 SUMMING AMPLIFIER OUTPUT AS-INPUT IDEAL AS-LEFT As-Found Limits As-Left Limits FOUND Detector Detector NM-3 10 NM-3 10 NM-3 10 A B Output Output Output Low Vdc High Vdc Low Vdc High Vdc Data Sheet 4

Calculation No. 2009-0002 Revision 0 Page B9 of B 18 Attachment B LIMITS

Calculation No. 2009-0002 Revision 0 Page B10 of B18 Attachment B It is reco~nmendedthat the calibration table for the drawer is broken into two separate tables as follows for the percent level indicator and the output from the summing amplifier.

Calculation No. 2009-0002 Revision 0 Page B l 1 of B18 Attachment B IN-42 NM-3 10 SUMMING AMPLIFIER OUTPUT AS-INPUT IDEAL AS-LEFT As-Found Limits As-Left Liinits FOUND Detector Detector NM-3 10 NM-3 10 NM-3 10 A B Output Output Output Low Vdc High Vdc Low Vdc High Vdc Current Current Vdc Vdc Vdc Data Sheet 4

Calculatio~lNo. 2009-0002 Revision 0 Page B12 of Bl8 Attachment B

Calculation No. 2009-0002 Revision 0 Page B13 of Bl8 Attachment B It is recommended that the calibration table for the drawer is brolten into two separate tables as follows for the percent level indicator and the output from the summing amplifier.

1N-43 PERCENT FULL POWER AS-INPUT IDEAL AS-LEFT As-Found Limits As-Left Limits FOUND Percent Percent Percent Detector Detector Full Full A B Low % High % Low % High %

Power Power Power Cul-sent Cun-ent Meter % Meter % Meter %

0 0 0.0 0.0 2.0 0.0 0.5 10.0 8.0 12.0 9.5 10.5 30.0 28.0 32.0 29.5 30.5 50.0 48.0 52.0 49.5 50.5 80.0 78.0 82.0 79.5 80.5 50.0 48.0 52.0 49.5 50.5 30.0 28.0 32.0 29.5 30.5 10.0 8.0 12.0 9.5 10.5 0 0 0.0 0.0 2.0 0.0 0.5

Calculation No. 2009-0002 Revision 0 Page B14 of BlS Attachment B

Calculation No. 2009-0002 Revision 0 Page B15 of B18 Attachment B Data Sheet 4

Calculation No. 2009-0002 Revision 0 Page B16 ofB18 Attachment B It is recommended that the calibration table for the drawer is broken into two separate tables as follows for the percent level indicator and the output from the summing amplifier.

Calculation No. 2009-0002 Revision 0 Page B17 o f B l 8 Attachment B Data Sheet 4 1(2)NR-45 1(2)N-44 Power Range Power I I

Calculation No. 2009-0002 Revision 0 Page B18 ofB18 Attachment B

Calculation No. 2009-0002 Revision 0 Page C1 of C9 Attachment C Process and Environinental Considerations 1.0 Reactor Protection Trip Setpoints 1.1. Analyzed Events The power range channels feed two reactor trip functions, the high range -high flux setting and the low range -high flux setting.

The high range -high flux setting reactor trip is credited as the primary trip in three analyses (Reference G. 18):

1. Rod withdrawal at power (RWAP)

2. Rod Control Cluster Assembly (RCCA) ejection (HFP cases)

3. Steam line break outside containment (SLB(0C))

This reactor trip is also a bacluplanticipatory trip for the following events:

1. Rod withdrawal from subcritical (RWFS)

2. Loss of load

3. Reduction in feedwater enthalpy

4. Excessive load increase

5. CVCS malfunction (boron dilution) at power

6. Steam line break inside containment (SLB(1C))

None of these backuplanticipatory trips has a process liinit associated with its respective analysis.

Therefore, they will not be considered in the setpoint evaluation.

The low range -high flux setting reactor trip is credited as the primary trip in two analyses (Reference G. 18):

1. Rod withdrawal from subcritical (RWFS)

2. RCCA ejection (HZP cases)

This reactor trip is a backuplanticipato~ytrip for the startup of an inactive reactor coolant loop.

No process limit is provided for this event; therefore, it will not be considered in the setpoint evaluation.

The analyses with analytical limits will be discussed separately.

1.1.1 Rod Withdrawal at Power An uncontrolled Rod Control Cluster Assembly (RCCA) withdrawal at power is a positive reactivity insertion that produces an increase in core heat flux. Since the heat removed fiom the reactor coolant system (RCS) by the steam generators is unchanged, T,,,, increases. A continued temperature increase would eventually result in Departure from Nucleate Boiling (DNB). A continued T,,, increase also has the potential, if uncheclted, to challenge the integrity of both the RCS boundaly and the main steam pressure boundary. An uncontrolled withdrawal of a RCCA at

Calculation No. 2009-0002 Revision 0 Page C2 of C9 Attachment C power could be the result of operator action or a malfunction of the rod control system. A spectsum of reactivity insertion rates, with the inaxiinuin reactivity insertion rate based on a rate greater than that for a simultaneous withdrawal of the two balks of greatest combined worth at maxilnuin speed, were analyzed for a range of power levels (Reference G.3 Section 14.1.2). For rapid RCCA withdrawal, analysis shows the reactor trips on power range high neutron flux -high setting shortly after the initiation of the event, with only small changes in T , , and RCS pressure, and a large margin to DNB is maintained. Slower RCCA withdrawal is of less interest here, as analysis shows the reactor trips on OTAT after a longer transient, however these cases result in larger RCS temperature and pressure increases than the rapid withdrawal (for very low reactivity insertion rates, steam generator safety valves relieve a significant amount of steam prior to the reactor trip). DNB margin is again maintained. The power range high neutron flux - high reactor trip is a primary trip for this accident. The analytical limit is 118% and the process sensor functional time is 100.219 seconds (Reference G.18). There is no loss of inventoiy to the containment in any rod withdrawal event; therefore nol-mal containment environmental parameters should be used in calculating uncertainties.

1.1.2 RCCA ejection (Hot Full Power cases)

The Hot Full Power (HFP) RCCA ejection cases assume control bank D is inserted to its insertion limit at the initiation of the event and there is a stuck rod adjacent to the ejected control rod. The RCCA ejection is a loss of coolant accident, with the break located in the reactor pressure vessel head, and some fuel melting is anticipated in the HFP cases, although there is no danger of sudden fuel dispersal into the reactor coolant (Reference G.3 Section 14.2.6). The high range -

high flux reactor trip is the primary trip for this accident. The analytical limit is 118% (Reference G.18). There is no process sensor functional time since the reactor trip occurs very early in the transient; therefore normal containment environmental parameters should be used in calculating uncertainties.

1.1.3 Steam Line Break Outside Containmeilt The high range - high flux reactor trip is the primary reactor trip signal for only the largest break cases at nominal full power for the SLB(0C) analysis (Reference C.3). The analytical limit is 118% and the process sensor functional time for the largest breaks is 8 seconds (Reference G. 18).

Since the steam line bealts in this analysis all occur outside containment, normal containment environmental parameters should be used in calculating uncertainties.

1.1.4 Rod Withdrawal From Subcritical (RWFS)

This accident is a primary system heatup event, producing an increase in neutron flux and core power, which could result in fuel damage, clad damage, or departure from nucleate boiling (DNB). The increased heat flux also expands the reactor coolant, potentially increasing primary system pressure sufficiently to challenge the integrity of the reactor coolant system (RCS) pressure boundary. The uncontrolled rod withdrawal fiom subcritical (10'~% of nominal power) assumes the simultaneous withdrawal of the two control banks with the maximum combined worth at maximum speed (Reference G.3 Section 14.1.1). This continuous reactivity insertion results in a vely fast power rise, reaching the low range - high flux setting setpoint at 10 seconds (References G.3 Section 14.1.1 and Table 14.1.1- 1). The low range - high flux reactor trip is a prilnaiy trip for this accident. The analytical limit is 35% and the process sensor functional time

Calculation No. 2009-0002 Revision 0 Page C3 of C9 Attachment G is 10 seconds (Reference G.18). The analysis shows the transient is tei~ninatedbefore any fuel damage or clad damage occurs, and the thermal flux remains low enough that DNB is not reached. There is no breach of the priinaly coolant system; therefore nonnal containment environmental parameters should be used in calculating uncertainties.

1.1.5 HZP RCCA Ejection The HZP RCCA ejection cases assume control bank D fully inserted and control banks B and C at their insertion limits (Reference G.3 Section 14.2.6); this configuration is the reason a reactor trip signal is required to mitigate the accident. The low range -high flux setting reactor trip is a primary trip for this accident. The analytical limit is 35% for this case. The RCCA ejection is a loss of coolant accident with attendant h e 1 damage; because the reactor trip occurs very early in the transient (Reference G.3 Section 14.2.6), normal environmental parameters should be used in calculating uncestainties.

1.2 Process Considerations Reference G.32 provides values for the process errors to be used with the power range reactor trips. The daily calibration of the power range channels, which is based on the results of the power calorimetric, accounts for the sensor (detector) effects of accuracy, drift, power supply, temperature, humidity, and radiation. Therefore, these effects can be neglected in calculating a loop error.

1.3 Environmental Considerations The summary of the analyzed events for which the power range reactor trips are credited demonstrates that only nol-mal containment environmental conditions would be in effect.

However, as discussed in the previous paragraph, even the normal environmental effects on the sensor (detector) can be ignored because of the daily calibration of the power range channels.

The power range detectors are energized during power operations. The detectors are rated for a maximum thel-mal neutron flux of 1 ~ 1 0 nv " (Reference V.lO). This is somewhat greater than the maximum expected thermal neutron flux during full power operation (Reference G.3 Figure 7.6-2). The detectors are rated for a maximum gamma flux of 5 x lo5 R/hs (Reference V.lO). Per Table 6-2 of WCAP-8587 (Reference G.20), the expected normal gamma dose at the detector location, 5 x lo4 Rthr, is somewhat less. Therefore, the radiation dose experienced by the detector assembly is within the design specifications and no additional enor due to radiation need be considered.

1.4 Reactor Trip Setpoint Values High Range - High Flux Trip The originally specified value for the high range reactor trip was 108 % of full power (Reference G.25). At around the same time, this value was placed in the PBNP Tech Specs as a limiting value for the setpoint-that is, the "field setting" or "field trip setpoint" could be any value below this limiting value. However, because there was no difference between the setpoint value specified in the PLS and the limiting value in the Tech Specs, any slight change in the setpoint

Calculation No. 2009-0002 Revision 0 Page C4 of C9 Attachment C value over the operational cycle-for example, due to instrument drift-would, if the setpoint were found outside the Tech Spec limit when the channel was tested, cause a Tech Spec violation.

As a result, the field trip setpoint for the trip was moved away from the Tech Spec limiting value and established at 107 % full power, a setting that was considered adequate to prevent this problem.

During the conversion of the PBNP custom Technical Specifications (CTS) to the "improved" Technical Specifications (ITS), which were based on the Westinghouse Owners Group (WOG)

Standard Technical Specifications (STS), the values that had appeared in the CTS were declared to be "Allowable Values" (Reference G. 11). Since, in the case of the high range trip, the field setpoint had been established by baclung off from the Tech Spec value to account for changes (e.g., drift) over the course of the operating cycle, the CTS values could be considered, in some sense, equivalent to Allowable Values.

However, there was no calculation that established the relationship of the CTS Tech Spec value to the value of the field setpoint-rather, for the reasons described above, this relationship was somewhat arbitrary. As a result, the Allowable Values in the ITS were taken directly from the values which had been in the CTS and which, in turn, had originally been considered to be limiting values for the field trip setpoint. In the case of the high range setpoint, the limiting value of 108% that had appeared in the CTS becaine the ITS Allowable Value. The field trip setpoint remained at 107%.

As described above, the originally specified field setpoint for this function was 108 % full power.

This is a typical trip setpoint value established by Westinghouse for this function. However, at PBNP, over time, this value was converted into an Allowable Value and the field setpoint was lowered to 107 %. For comparison, the WOG STS (References G.38 and G.39), on which the PBNP ITS are based, lists a setpoint value of < 109% RTP for this function and a higher value (1 11.2 % RTP) for the Allowable Value.

For Extended Power Uprate, the Analytical Limit for the high range -high flux trip setpoint was changed from 118% to 116% for the RWAP transient [References G-40 and Westinghouse calc CN-TA-08-55 Rev 01. Therefore, a separate Limiting Trip Setpoint calculation for the EPU condition is necessary for the high range -high flux trip setpoint.

Low Range -High Flux Trip The originally specified value for the low range trip was 25% of full power (Reference G.25).

However, as in the case of the high range trip, this same value becaine the Tech Spec limiting value for the setpoint, and the field setpoint was lowered to 20 % to prevent Tech Spec violations.

The current field setpoint of 20% provides significant margin to the Analytical Liinit of 35%,

even when instrument uncertainties are considered. Although the field setting could be restored to the original 25% value and still have sufficient margin, no recommendation is made to increase the field setting at this time.

For Extended Power Uprate, the low range - high flux trip setpoint Analytical Liinit of 35% was retained for the Rod Withdrawal from Subcritical analysis. Therefore, a separate EPU calculation

Calculation No. 2009-0002 Revision 0 Page C5 of C9 Attachment C for this setpoint is not necessary, and the cursent power level calculation will continue to be valid for EPU.

2.0 Reactor Protection Interlocks The power range channels also feed several reactor protection system interloclts: P-7 perlnissive, P-8 permissive, P-9 permissive, and P-10 perinissive. These perinissive interlocks are described below:

The P-7 peinlissive (low power reactor trips block) automatically bloclts six reactor trips when either power range power or turbine power (as reflected by first stage turbine impulse pressure) decrease to approximately 10% RTP. The reactor protection function of this pel-missive is to automatically re-instate the reactor trips when power is increased above the P-7 setpoint. Two-out-of-four power range channels or either first stage turbine impulse pressure signal above approxilnately 10% de-energize the P-7 relays on increasing power (References 0.33, D.34, D.37, and D.38). The following reactor trip functions are blocked by the P-7 permissive:

e 212 loop loss of reactor coolant flow r 212 reactor coolant pumps breaker trip r RCP 4 kV bus undervoltage Pressurizer low pressure 0 Pressurizer high level e Turbine trip The original power range input to P-7 was 10 % of full power. For reasons described in Section 1.4.1 above, the same 10 % value also became the Tech Spec limiting value for the P-7 setpoint, and the field setpoint was lowered to prevent Tech Spec violations. At present, the field trip setpoint for the unblock function is 9.5% RTP and the reset (or block) function is 8.5% RTP (Reference P. 18 and P. 19). These values are the same as the P- 10 permissive, although the reactor protection functions for these permissives, automatic unblocking of the reactor trips, occur at the opposite settings. This characteristic is due to a single bistable relay driver in each channel feeding both the P-10 permissive input and the nuclear instrumentation input to the P-7 permissive. The consequences of this situation are discussed in the configuration consideration section.

2.2 P-8 Permissive The P-8 permissive blocks a reactor trip when a single reactor coolant loop loses flow with power range power below the P-8 setpoint. The reactor protection function of this pel~nissiveis to re-instate the reactor trips when power is increased above the P-8 setpoint. The power range channels feed a 214 logic inatrix that de-energizes the P-8 relays at the setpoint, currently at 49%

(References P.18, P.19,D.33, and D.34). The reactor trips blocked by the P-8 pel-missive are:

%. loop loss of reactor coolant flow r %. reactor coolant pumps breaker trip

Calculation No. 2009-0002 Revision 0 Page C6 of C9 Attachment C The original power range input to P-8 was 50 % of full power (Reference G.25). For reasons described in Section 1.4.1 above, the same 50 % value also became the Tech Spec limiting value for the P-8 setpoint, and the field setpoint was lowered to prevent Tech Spec violations. At present, the field trip setpoint for the unblock function is 49% RTP (References P. 18 and P. 19).

For EPU, the P-8 setpoint was re-analyzed by Westinghouse calculation CN-TA-08-52 Revision 0 [References G.40 and C.51 for an Analytical Limit of 45% rather than a nominal value of 50%.

Further, the Westinghouse calculation stipulated that, with instrument uncertainty, the TS Allowable Value should be set at 35%. Although pe~~nissives do not typically have a specific Analytical Limit, establishing this limit forces that actual field setting for P-8 to be less than the AL by at least the amount of uncertainty. Therefore, the P-8 permissive field setting should be established in this calculation based on the 45% Analytical Limit and consideration given to setting the TS Allowable Value to 35% as recommended by Westinghouse, provided the uncertainty of the channel is an value less than 10% (the difference between the AL and the AV).

This would make the required field setting for the P-8 setpoint some value below 35%.

2.3 P-9 Permissive The P-9 permissive blocks the reactor trip on turbine trip signal below approximately 50% power when the condenser is operating normally. With a condenser steam dump capability of 40% and rod motion, Point Beach can sustain a turbine trip below 50% without requiring a reactor trip.

Above 50%, steam dump capability is not sufficient to absorb the RCS energy due to a loss of load, and a reactor trip on turbine trip is required. The reactor protection function of the P-9 permissive is to unblock (remove) the turbine trip reactor trip when any of the following conditions occur:

Loss of both circulating water pumps c condenser vacuum is 22 inches Hg decreasing on either transmitter e power range power is greater than 49% RTP (two-out-of-four coincidence)

The power range channels feed a 214 logic matrix that de-energizes the P-9 relays on increasing power at 49% (References P. 18, P. 19, P.29, D.33, D.34, D.37, and D.38).

The original power range input to P-9 was 50 % of full power for plant startup tests (Reference G.25). For reasons described in Section 1.4.1 above, the same 50% value also became the Tech Spec limiting value for the P-9 setpoint, and the field setpoint was lowered to prevent Tech Spec violations. At present, the field trip setpoint for the unblock function is 49% RTP (References P.18 and P.19).

For EPU, the P-9 setpoint has been re-analyzed by Westinghouse calculation CN-CPS-08-20 Revision 0 [References G.40 and C.41 to determine if the existing P-9 setpoint is adequate to provide loss of load protection for the reactor when power is below the existing -50% setpoint.

The analysis determined that multiple P-9 setpoint values were needed for higher power levels under EPU conditions based on the operating full load T,,,,. P-9 must be reduced to 35% if full load Tavg is between 558°F and 572°F. For full load T,,, between 572°F and 577"F, the existing setpoint is adequate to block the reactor trip below 50%. Therefore, for EPU, a dual setpoint will be specified for this permissive. The specifics of the P-9 setpoint change are addressed in Section 8.4.4 of this calculation.

Calculation No. 2009-0002 Revision 0 Page C7 of C9 Attachment C The P-10 pelmissive permits manual blocking of the intennediate range high neutron flux reactor trip and the power range high neutron flux - low setting reactor trip when reactor power is greater than 9.5% RTP (Reference P. 18 and P. 19). It also automatically blocks the source range high neutron flux reactor trip and de-energizes the source range detectors. However, the protection function of this permissive is performed when power range power decreases to 8.5% RTP (Reference P.18 and P.19) and automatically unbloclts the above trips. The unblock logic is 314 channels at 8.5% decreasing. This actuation energizes the P-10 relays, which then de-energize the intermediate range block relays and the power range block relays. This function also removes the P-10 source range block signal, allowing automatic source range channel restoration when power is reduced to the P-6 permissive reset point (References P.18, P.19, D.35, and D.36).

The original P-10 setpoint was 10 % full power. For reasons described in Section 1.4.1 above, this same 10 % value also became the Tech Spec limiting value for the P-10 setpoint, and the field setpoint was lowered to prevent Tech Spec violations. At present, the field trip setpoint for the unblock function is 8.5% RTP. The Tech Spec also contains a low limit value of 3 % RTP as is discussed in the next section.

2.5 Configuration Considerations As noted in Figure 6.2-1, permissives P-7 and P-10 share a common bistable relay driver, but they perform different functions. As neutron flux increases, the P-7 relay is de-energized when the setpoint is reached. As neutron flux decreases, the P-10 relay is energized when the setpoint is reached. However, because of the bistable deadband (or "lockup"), the setpoint values for the two functions cannot be the same, and the two functions cannot be considered independently, as the setpoint of one function is the reset point of the other and vise versa. The setpoint evaluations of P-7 and P-10 must talte this equipment configuration into account when establishing the setpoints for these permissives. This situation was recognized early in plant operation; the Atomic Energy Commission (Reference G.35) was requested to change the required automatic unblock of the intennediate range high neutron flux reactor trip and the power range high neutron flux - low setting reactor trip to 5 5% of rated power to allow for a 2% deadband in the P-10 bistable. Point Beach later modified this request (Reference G.36) to allow settings of L 10% (*

2%) for P-7 and 5 10% (rt 2%) for P-10. In August of 1975, the NRC (Reference G.37) changed the interlock specification to > 9% ( 5 1%) for P-7 and 2 9% (rt 1%) for P-10 to account for the 2% deadband. The current configuration (Reference P. 18 and P. 19) uses a 1% power deadband (or lockup); the calculation should also use a 1% deadband setting in establishing the permissive setpoint / reset settings.

An additional consequence is that no calibration procedure specifically addresses the power range inputs to the P-7 permissive. However, calibration of the P-10 permissive perfolms the calibration of the P-7 permissive as well. Therefore, ICP 02.022 (References P.18 and P.19) should be used as the reference calibration for the nuclear instrumentation inputs to P-7.

Calculation No. 2009-0002 Revision 0 Page C8 of C9 Attachment C 2.6 Permissive Setpoints As described above, the existing field trip setpoints for these functions were moved away from the originally recommended values to prevent Tech Spec violations and the originally recommended setpoint values were converted into Tech Spec Allowable Values. It is recommended that the nominal setpoints (field trip setpoints) be reset to the originally specified values from Section 1.3 of WCAP-7116 (Reference G.25) and that the Tech Spec Allowable Values for these functions be re-established based on these nominal setpoints, in accordance with the practice of the Standardized Tech Specs (STS). These nominal setpoints are:

0 P-7: 10% RTP 0 P-8: 50%RTP 0 P-9: 50% RTP 0 P-10: 9%RTP Refer to Section 8.4.4 of this calculation for discussion of the setpoint changes required for Extended Power Uprate conditions.

The nominal setpoint values should be the unblock functions, since removing the permissive block (unblocking) perfolms the protection function defined in IEEE-279 (1968 version) and FSAR Section 7.2.1.1 .o (Reference G.3). This means the allowable values for P-7, P-8, and P-9 would be set higher than the nominal setpoints and the allowable value for P-10 would be set lower than the nominal setpoint. The block (reset) should be set lower than the nominal trip setpoint by I% for P-7, P-8, and P-9; the block should be set higher than the nominal trip setpoint by 1% for P-10. For the P-10 and P-7 pei~nissives,this means the reactor trips blocked by P-7 will be automatically unblocked at 10% power and the P-10 per-missive will allow manual blocking of the intermediate range and power range low range trips at the same 10% power level.

At 9% power, the high flux reactor trips will be automatically unblocked and the P-7 trips automatically blocked.

None of these interloclts are credited as primary or backuplanticipatoly trips in any accident analysis (Reference G. 18). The block permissives and block permissive resets are considered nominal setpoints and no fonnal setpoint evaluation or calculation of the instrument uncertainty for these interloclts is required (Reference G.32). However, refer to Section 8.4.4 of this calculation for a discussion of changes in the P-8 and P-9 permissives required for EPU that involve uncertainty considerations.

3.0 Rod Withdrawal Stop The power range high neutron flux rod withdrawal stop inhibits outward control rod motion (in automatic or manual) when 1 of 4 power range channels reaches 105% RTP (References P.18, P.19, and D.41 - 0.46). The rod stop is considered a supervisory, not a protective function (Reference G. 11 Section 5.3) and is not credited in any accident analysis. Therefore, no limiting trip setpoint needs to be established and no fonnal uncertainty calculation is required. There is no Tech Spec Allowable Value associated with this function, and the 105% RTP nonlinal setpoint is the originally supplied value (

Reference:

G.25, Section 3.1.1).

Calculation No. 2009-0002 Revision 0 Page C9 of C9 4.1 Loss of Detector Voltage Alarm The setpoint document for alai~nsand operational adjustments also contains a specific setpoint for power range loss of detector voltage, 700 Vdc (References P.20 - P.27). The loss of detector voltage alarm serves to alert operators in the event of a loss of voltage. The loss of voltage alarm is not a process variable and a nominal setting, based on engineering judgment and past practice, is appropriate to determine this setpoint. Therefore, it is unnecessaiy to determine instrument uncertainty or to perfoim a formal setpoint calculation. The original guidance set this alaim at 100 Vdc below the operating point (Reference G.25), and that guidance is still in place. If no operational problems have arisen using this value, there is no reason to ~nalteany change. The 700 Vdc setpoint is acceptable as it stands and no additional evaluation is necessary.

4.2 Rod Drop Alarm The rod drop indication responds to dynamic power range channel signal changes associated with a dropped rod condition, but does not respond to slower signal changes consistent with nollnal plant operation. The rod drop alann circuit compares each channels nuclear power signal with the same signal after it is conditioned by an adjustable rate lag circuit (Reference G.3 Section 7.6.1.3.b). The alarm logic is one-out-of-four channels (References D.35 and D.36). While this alarm could alert operators to a dropped control rod condition, the accident analysis does not tale credit for the annunciator (Reference G.3 Section 14.1.3). The alarm signal conditioning produces an output that actuates the alann when the input power decreases by 2.5% in 5 seconds (References P.20 - P.27). Because the rod drop alann is not credited in any accident analysis, no formal setpoint evaluation or uncertainty calculation is required (Reference G.18). The original setpoint for this alarm was a 5% power drop in 5 seconds (Reference G.25); at some point, the power decrease was changed to 2.5%. This change is in the conservative direction, and, since the change has not resulted in spurious alarms, no additional evaluation is needed.

Calculatioil No. 2009-0002 Revision 0 Page Dl of D5 Attachment D From: -

Jim Nagell 1 Kim Strickland Point Beach Nuclear Plant To : -

Dean Crumpacker Sargent & Lundy Mod or Tracking Number: ,CRR Project Date: 6/4/07 DIT No: CRR-I&G 012 Mod TiUe: Trealment of Backup Trips and ~enkissives Unil 1 l.lUnit 2 U Quality Plant: PBNP Common B Classification:

drift value. DO-I01 dbes not currently address thls Issue. It will be revlsed tb do so and until then the information provided by thls DIT and Figure 3.3.8-2 gives sufficient Information for use within CRR calculation revisions.

Check i f applicable:

Thls DIT confirms information previously transmitted orally o n by Page 1 of 2

Calculation No. 2009-0002 Revision 0 Page D2 of D.5 Attachment D DISTRIBUTION(Recipients should receive all attachments unless otherwise indicated. All attachments are uncontrolledunless otherwise lndicaled)

PREPARED BY (The Preparer and Approver may be the same person.)

Jim Nageil Sr.Engineer 6/17 Preparer Name Position Date APPROVED BY (The cognizant Engineering S u p e ~ s ohas r release authorily. Consult the Design Interface

&.,q Date A copy of the DIT (along with any atlachments no1on file) should be sent lo the modification611e Page 2 of 2

Calculatioil No. 2009-0002 Revision 0 Page D3 of D5 Attachment D Insert to DG-101 Scction 3.3.8 Treatment of Backup Trivs and Permissives Bachplanticipalory trips and permissives are protection system features that are not credited in accident analyses for performing primary protective fi~nctions.Therefore, setpoints for tlrese features lack an analytical limit for estahiishing a limiling trip setting. Although they arc not credited in analyses, backuplmticipntory trips enhance overall reliability and diversity of the protection systcn~s(i.e., provide cfefense-in-depth). Permissives (also called "operating bypasses" in IEEE-279) automatically enable protective fUtrctions at predetermined settings. For these rcasons, backup trips and pamissives are regarded as safety functions of Ule protection system, but perform no active role as trip functions assumed in accident analyses. By using a "graded approach" (ISA-TR67.04.09-2005) philosophy toward setpoints that lack analytical limits, backup trips and permissives can be calculated with less rigor than primary protection functions.

Based on discussion and conespondencc' with Westinghousc regarding how setpoints are determined for backup trips and ~)cm~issives, instrument uncertainties are neither required nor ncccssary to establish these setp6ints. Setpoint uncertainties arc not required because, unlike primary protective trips that havc analytical limits, backup trips and pern~issiveshavc no limit against wl~icllthe uncertainties are applied. Instead, the setpoints for these protection system features nrc nominal values. These nominal values were typically provided for original plant operdtion (e.g., in WCAP-7116, Precautions, Limitations, and Settings) or have proven lo be acceplablc for safe and reliable operation over the years since plant startup. Therefore, historical precedent is an acceptable technical basis for establishing the nominal setpoint valuc for backup trips and pemrissives.

Some nccidont analyses may contain a "process limjt valuc for a backup trip as an input to the analysis. This analysis input may have been used to determine which of several t r i ~functions o c c k e d first in the accident, to determine which parameter performed the primaGtrip function.

When the analysis demonstra~esthat a backup. trip. occumnc? - at the ~rocesslimit does not perform the primary trip function, the process limit should not he regarded as an analytical limit.

Although uncertainties arc not needed to determine a nominal selpoint for backup trips and pcmlissives, an evaluatio~~ should be made Lo verify that Ihe nominal setpoint does not interfere with other operational limitdsettings for tljc same parameter. Loop uncertainties may also be needed for other non-protection reasons such as determining setting tolerances.

'l'echeic.al S~ecificationValues for Backun Trins and Permissives NRC regulation 10CFR50.3G requires that I-imiting Safety System Settings (LSSS) be specified for protection system trips that protect Safety Limits. As discussed above, backup trips and pern~issivesare not based on safcty analysis limits. As a result, these fimctions do not meet the strict definition of a ISSS. However, back~~p/pcnnissive fi~nctionsare currently assigned a Tech Spec Allo~vableValue, even though the AV tcmr is only appropriate for primary trips.

' I'agc 6 of Wcstinghousc letter WEP-94-525dated 2/1/94.

Calculatio~lNo. 2009-0002 Revision 0 Page D4 of D5 Attachment D As dcfincd in the Teclmical Specifications, Allowable Values arc as-found limits that apply to the portion of an instrument loop that is tested periodically during the Channel Operational Tesl (COT). Any uncerlainties used to determine the Allowable Value are limited to the portion of the loop testcd during the COT. The COT typically applies to the bistable portion, excluding Ule field sensor.

Allowrible Values for backup trips and permissives should be determined by applying a "3-sigma" drift value for the COT-tested instruments to the as-left setting tolerance for thc COT-tested instruments (is., the rack as-left tolcrance), rather than a 2-sigma drift value used to dctcrmine the as-found limit, A 3 0 drift value is an appropriate outlier criterion for an Allowable Value for backup trips and permissives that lack an analytical tllimt. Applying the 30 drift to the rack as-left tolerance ensures that driA occurring beyond the AV limit is significant to 99.7% probability and that a channel exhibiting 3 0 drift is declared inoperable rather than just evaluated for opcrability (which is the purpose of a Technical Specification Allowable Value, as compared to an as-found limit).

The rack as-left tolerance (RAL) applied during the COT should eitlrer bc derived in the calculation or justified as a calculation assumption. See Section 3.3.8.6 [ofDG-JOl] for how to dctemtine the rack as-left setting tolerance.

The rack 3 0 drift value (Rd3) cmt be derived &om the 2 0 rack drift value (Rd) by multiplying Rd by 1.5.

As discussed in Section 3.3.8.6, the 2 0 rack drin value should be obtained either from as-IefUas-found driR analysis afthe COT inshument string, or frortl Ule SRSS of the individual COT instrument drift values.

For an increasing trip, the Allowable Value for backup trips and permissivcs is then determined using the SRSS of RAL and Rd3,, as follows:

A diagram of Ute relationship between the FTSP, RAL, I W , and Allowable Value for backup trips and permissives is shown in Figure 3.3.8-2.

Calculation No. 2009-0002 Revision 0 Page D5 of D5 Attachment D Cbdm channel INOPEMLS IUue CAP.

rmslale ad maWa!oi(*

.A. Allowable Value (AV)

RewlmR;kae W a n d %'&a&

Run6hralr

...... - Field Trip Setpoint (FTSP) ~o~don NeCeW

.:.>w.7<:.G!.:s.:s<<:s$

~:~:.*.*.y$,:.*.x.;<.:.:.:

$>;&#:::,:,:zA;s.$

wmi XgdE*gzI Normal Operating Band

.)*.,.:.:.,.:<,, ..*

..: ..:*;* :&!?a3 Figure 3.3.8-2 Backup TriplPermissive Allowable Value (for increasing trip)

ENCLOSURE 3 NEXTERA ENERGY POINT BEACH, LLC POINT BEACH NUCLEAR PLANT, UNITS 1 AND 2 LICENSE AMENDMENT REQUEST 261 EXTENDED POWER UPRATE RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION STEAM LINE PRESSURE INSTRUMENT LOOP UNCERTAINTY / SETPOINT CALCULATION 127 pages follow

Table of Contents Calculation No . PBNP-IC-39 Revision 4 Page 16 of 117

1.0 BACKGROUND

. PURPOSE. AND SCOPE OF CALCULATION ..............................19 1.1 Background...................................................................................................... 1 9 1.2 Purpose ...................................................................................................................... 19 1.3 Purpose of This Revision ......................................................................................... 19 1.4 Scope.................................................................................................................. 1 9 1.5 Instrumentation Evaluated ..................................................................................... 20 1.6 Superseded Station Calculations ............................................................................21 2.0 ACCEPTANCE CRITERfA ............................................................................................. 22 3.0 ABBREVIATIONS.............................................................................................................23 3.1 AL Analytical Limit ............................................................................................... 23

4.0 REFERENCES

.......................................................................................................... ....24 4.1 Genera1....................................................................................................................2 4 4.2 Drawings ................................................................................................................... 28 4.3 Procedures ................................................................................................................ 29 4.4 Vendor ..................................................................................................................... 3 1 4.5 Calculations .............................................................................................................. 32 5.0 ASSUMPTIONS .................................................................................................................34 5.1 Validated Assumptions ............................................................................................ 34 5.2 Unvalidated Assumptions........................................................................................ 36 6.0 DESIGN INPUTS ............................................................................................................... 37 6.1 Loop Definitions ....................................................................................................... 37 G.2 Loop BIoclc Diagram ................................................................................................37 6.3 Component Models and Tag Numbers ..................................................................37 6.4 RangeList .................................................................................................................38 6.5 Cables ........................................................................................................................ 39 6.6 Environmental Considerations ............................................................................... 40 TLE 43

Table of: Contents Revision 4 Page 17 of 117 6.7 Existing Analytical Linlit (AL). Field Trip Setpoint (MTSP). and Existing 7.0 METHODOLOGY .............................................................................................................47 7.1 Uncertainty Determination ..................................................................................... 47 7.1.5 Parametric Values ....................................................................................................57 7.2 Drift Considerations ................................................................................................ 59 7.3 Channel Check Tolerance Equation Sumnlary (CCT) ........................................ 59 7.4 Setpoint Calculations ........................................................................................59 7.5 Process Error Calculation ................................................................................... 6 0 8.0 BODY OF CALCULATIONS ........................................................................................... 61 8.1 Device Uncertaiaty Analysis ...............................................................................61 8.2 Device Uncertainty Summary ................................................................................. 86 8.3 Total Loop Error ......................................................................................................89 8.3.5 Total Indicator Loop Error for Parametric (TLE3,) ...........................................94 8.4 Acceptable As-Found and As-Left Calibration Tolerances ................................. 95 8.5 Channel Checlc Tolerance .......................................................................................99 8.6 Low Steam Line Pressure Safety Injection Setpoints ......................................... 100 Using Equation 7.1.6.3 to determine the bistable 3a drift value, .................................101 8.8 Parametric Value Evaluation .............................................................................. 105 9.0 RESULTS AND CONCLUSIONS .................................................................................. 106 9.1 Total Loop Error .................................................................................................... 106 9.2 Acceptable As-Left and As-Found Tolerances .................................................... 106 9.3 Limiting Trip Setpoints, Operability Limits (OL), and Recommended Tech Spec Changes .....................................................................................................................107 9.3 Channel Check Tolerance .....................................................................................109 9.4 Setpoint Evaluations ............................................................................................ 109 9.5 Technical Specification Ailowable Values ..........................................................109 9.6 Paranletric Value Evaluation ............................................................................... 110 9.7 Limitations ..............................................................................................................111 9.8 Graphical Representation of Setpoints ................................................................112

Table of Contents Calculation No. PBNP-IC-39 Revision 4 Page 18 of 117 10.0 IMPACT ON PLANT DOCUMENTS ............................................................ ......,.,...114 11.0 ATTACHMENT LIST .......................,................................ . . . . .. ........ 1 1 7

Calculation PBNP-IC-39 Revision 4 Page 19 of 117

1.0 BACKGROUND

, PURPOSE, AND SCOPE OF CALCULATION

1.1 Background

The Steanl Line Pressure is nlonitored by the associated instrumentation shown in References D.9 and D:10. Two steam generators transfer energy from the reactor coolant system (RCS) to the main steam system. One main steam line is connected to each of the generators and there are three steam line pressure instrumentation channels for each main steam line. The main steam line pressure cha~mels-l(2)P-468, 1(2)P-469, l(2)P-482, l(2)P-478, l(2)P-479, and l(2)P-483-perform protection, control, alarm, and indication functions.

It is important to note that steam line pressure refers to the pressure in the steam flow piping downstream from the steam generator while steam generator pressure refers to the pressure inside the steam generator itself. The transmitters analyzed in this calculation measure steam line pressure, as they are tapped on the steam flow piping (Ref. D.9 and D. 10). Therefore, Steam Line Pressure is used to describe the measurement throughout this calculation. However, since no transmitters exist at the steam generator, the steam line pressure transmitters are also used to provide an indirect measurement of steam generator pressure when needed.

1.2 Purpose The purpose of this calculation is to determine the instrument ullcertainties associated with the low steam Iine pressure safety injection setpoint, evaluate the low steam line pressure safety injection setpoint, and determine the instrument uncertainties associated with the control room indication of steam Iine pressure.

1.3 Purpose of This Revision This revision determines Operability Limits (OL) associated with the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint for the purpose of determining channel operability during Technical Specification surveillance testing. This revision also updates the Limiting Trip Setpoints to include EPU setpoints based on revised Analytical Limits.

1.4 Scope This calculation determines the calibration values associated with the Steam Line Pressure instruments. The scope of this calculation is listed below:

P Determine Operability Limits (OL) for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

Calculatioi~PBNP-KC-39 Revision 4 Page 20 of 117 9 Determine loop conlponents needed to evaluate Low Steam Line Pressure Safety Injection setpoint and indication functions.

9 Determine the total loop error (TLE) for the indication loop under normal and accident operating conditions for use in WEP-SPT-20 for EOP setpoints.

9 Determine the TLE for the bistable loop under accident operating conditions.

> Dete~minethe TLE for the indicator and PPCS to determine compliance with the station's values used in the Tech Specs.

9 Detetmine acceptable As-Found and As-Left calibration tolerances for applicable components.

> Calculate channel check tolerance (CCT).

9 Evaluate the existing field trip setpoint (FTSP) and the Allowable Value (AV) for the Low Steam Line Pressure Safety Injection sewoint.

9 Determine the parametric values used for Tech Spec surveillance.

P Determine tra~lsrnitteruncertainties for use in PBNP-IC-40 "Steam FlowIFeedwater Flow Mismatch lilstmnent Loop UncertaintyISetpoint Calculation" under nornlal conditions.

1.5 Instrumentation Evaluated This calculation evaluates the plant equipment listed in the table below. The instrument loops are the same for Unit I and Unit 2. See Sections 6.2, 6.3, and 6.4 of this calculation for instrument specifications, parameters, and loop configurations.

Table 1.5-1: Ii~strumentationList

CaXcuiation PBNP-IC-39 Revision 4 Page 21 of 117 1.6 Superseded Statloll Calculations The following existing calculation(s) will be superseded upon issuance of Revision 4 of Calc. PBNP-IC-39:

r Calculation PBNP-IC-39, "Low Steam Line (Steam Generator) Pressure Safety Injection Instrument Loop Uncertainty / Setpoint CalcuIation7',Rev. 3

Calculation PBNP-IC-39 Revision 4 Page 22 of 117 2.0 ACCEPTANCE CRITERIA This calculation evaluates the adequacy of the existing Low Steam Line Pressure Safety Injection Field Trip Setpoint (FTSP). The FTSP is acceptable if the following criteria are met:

2.1 Positive margin is required between the Limiting Trip Setpoint (LTSP) and the Field Trip Setpoint (FTSP) for primary trips. The LTSP is calculated to ensure that the instrument channel trip occurs at or before the associated AL is reached. The LTSP is then compared to the FTSP to ensure that margin exists between the LTSP and the FTSP. Margin exists if the 3FTSP is less than the LTSP (for increasing setpoints) or the FTSP is greater than the LTSP (for decreasing setpoiilts). This criterion only applies to primary trips because baclmp trip hxlctions and permissives lack an analytical limit and therefore are not required to trip at a paxticular value to support the accident analyses.

2.2 The Margin-to-Trip values determined from the Low Steanl Pressure Safety Injection T ~ i p Setpoint (FTSP) must be above the Limiting Trip Setpoint to protect the rniniixlum process pressure analytical limit (AL).

2.3 The FTSP for the Low Steam Pressure Safety Injection Trip must be no lower than the Limiting Trip Setpoint as detailed in Figure 9.8.1.

2.4 The Operability Limits calculated for primary trips must be at or more conservative than the corresponding Limiting Trip Setpoint. This will allow the Technical Specification tables for RPS and ESFAS trip functions to be revised to insert the LTSPs as new Allowable Values for the primary trip hnctions but use the more restsictive Operability Limits for channel operability detemination during surveillance (COT) testing.

2.5 Channel Check Tolera~lce(CCT) is the maximum expected deviation between channel indications when performing a qualitative assessment of channel behavior during operation.

The calculated CCT will be compared to the existing CCT to ensure that the existing CCT is 2 the calculated CCT. If the existing CCT is non-conservative, a recommendation will be made to revise the existing CCT to satisfy the calculated CCT limit.

This calculation also evaluates the steam generator pressure parameteric value.

Parametric values are limits placed on specific plant parameters to ensure Tech Spec conlpliance.

The calculated parametric values are compared to the existing parametric values, which appear in an operator log, to ensure that the existing parametric is 5 to the calculated parametric for an increasing process or the existing parametric is 2 to the calculated parametric for a decreasing process.

Calculation PBNP-IC-39 Revision 4 Page 23 of 1.17 3.0 ABBREVIATIONS 3.1 AL Analytical Limit 3.2 AV Allowable Value 3.3 BAF Bistable Acceptable As-Found 3.4 BAL Bistable Acceptable As-Left 3.5 CCT Channel Check Tolerance 3.6 COT Channel Operational Test 3.7 CRI Control Room Indication 3.8 EOP Emergency Operating Procedure 3.9 ESP Engineering Safety Featuses 3.10 FSAR Final Safety Analysis Report 3.11 FTSP Field Trip Setpoint 3.12 HELB High Energy Line Break 3.13 IAF Indicator Acceptable As-Found 3.14 IAL Indicator Acceptable As-Left 3.15 VIM Current-to-Cul-re~ltRepeater Acceptable As-Found 3.16 YIAL Current-to-Current Repeater Acceptable As-Left 3.17 LOCA Loss of Coolant Accident 3.18 LTSP Limiting Trip Setpoint 3.19 M&TE Measurement and Test Equipment 3.20 MSLB Main Steam Line Break 3.21 OL Operability Linlit 3.22 PE Process Ersor 3.23 PBNP Point Beach Nuclear Plant 3.24 PL Process Limit 3.25 PPCS Plant Process Computer System 3.26 PPCSAF PPCS Acceptable As-Found 3.27 PPCSN, PPCS Acceptable As-Left 3.25 PS Process Span (engineering unit) 3.29 RAD Radiation Absorbed Dose 3.30 RAJ? Rack Acceptable As-Found 3.31 RAL Rack Acceptable As-Left 3.32 RE Rack Esror 3.33 SM Sensor Acceptable As-Found 3.34 SAL Sensor Acceptable As-Left 3.35 SLB Steam Line Break 3.36 SRSS Square Root of the Sum of the Squares 3-37 TLE Total Loop Error 3.38 TRM Technical Requirements Manual 3.39 TSR TRM Su~veillanceRequirement 3.40 Tech Spec PBNP Technical Specifications 3.41 Xmtr Transmitter

Calculation PBNP-IC-39 Revision 4 Page 24 of 117 4.0 FWFERENCES The revisions andlor dates of the references in this section are current as of 1/02?12009.

4.1 General G.1 Point Beach Nuclear Plant Design Guideline DG-101, Instmient Setpoint Methodology, Rev. 4 0.2 Point Beach Final Safety Analysis Report, Section 9.5 (dated June 1999), Section 9.8.1 (dated August 2008), Section 11.6.2 (dated June 2002), and Table 7.6-1 (dated August 2008)

G.3 Not Used.

G.4 Deleted per Rev, 2 of this CaIculation.

G.5 ASME Steam Tables for Industrial Use, based on IAPWS-IF97.

G.G Deleted per Rev. 2 of this Calculation.

G.7 PBNP Condition Report A/R No. 141685 (CR 95-109) Evaluation, dated February 22,1995 G.8 Not Used.

G.9 Not Used.

G.10 Not Used.

(3.11 Not Used.

G. 12 Not Used.

G. 13 Not Used.

G. 14 Not Used.

G,15 Not Used.

G. 16 PBNP CARDS System for the following cables:

Calculation PBNP-XC-39 Revision 4 Page 25 of 117 Not Used.

Not Used.

Bechtel Co~orationSpecification No. 6115-M-40, "Specification for Heating, Ventilating, and Air Conditioning Controls", Rev. 1 WCAP-8587, "Metl~odofogyfor Qualifying Westinghouse WRD Supplied NSSS Safety Related Electrical Equipment", dated March 1983, Rev. 6-A The Rockbestos Company Report QR-7804, "Report on Tests to Establish Insulation Resistance vs, Temperature Characteristic for Firewall I11 hadiation Cross-Linked Polyethylene Constructions for Class 1E Service in Nuclear Generating Stations", dated January 1985 Point Beach Nuclear Plant Technical Specifications, Section 3.3.2, B3.3.2, Amendment 201(U1) and Amendment 206 (U2)

PB 634, "Specification for Safety Assessment System and Plant Process Computer System for the Point Beach Nuclear Plant PPCS 2000", Rev. 3 Walkdown Calculation No. PBNP-IC-39, dated 6/12/06 (Attachment B)

Modification Package MR 99-003, "HELB Walls Doors and Blow-Off Panel in the CCW HX Room to Resolve FIELB Issue", completed 12/09/2003 Report 1-PM-468A, "Instnunent Traveller Sheet - Rehrbishment Project", dated 4117/89 Report 1-PM-469A, "Instrument Traveller Sheet - Rehbishment Project", dated 4/8/90 Report I-PM-482A, "Instrument Traveller Sheet - Refurbishtnent Project", dated 4/17/89 Report 2-PM-468A, "Instrument Traveller Sheet - Rehrbishment Project", dated 10/2/89

Calculation PBNP-ZC-39 Revision 4 Page 26 of 117 Report 2-PM-469A, "Instrument Traveller Sheet - Refurbislunent Project", dated 1017189 Report 2-PM-482A, "Inst~mentTraveller-Sheet - Refbrbislunent Project", dated 10116/89 Repoxt 1-PM-478A, "Instrument Traveller Sheet - Refurbishment Project", dated 4/24/89 Report 1-PM-479A, "Instrument Traveller Sheet - Refurbislment Project", dated 4119190 Report 1-PM-483A, "Instrument Traveller Sheet -Refurbishment Project", dated 4120189 Report 2-PM-478A, "klstrument Traveller Sheet - Refurbishment Project", dated 10/7/89 Repol-t 2-PM-479A, "Instrument Traveller Sheet - Refurbishment Project", dated 1017189 Repox-t 2-PM-483A, "Instrument Traveller Sheet - Refurbishment Project", dated 10119/89 Tyco Electronics (Raycheln) Report EDR-5336, "Nuclear Product Requalificatio~l Testing", Rev, 5, dated 9/6/05 Franklin Technical Report F-C5 120-1, "Qualification Tests of Electx-ical Cables in a Simulated Steam Line Break (SLB) and Loss-of-Coolant Accident (LOCA)

Environment", dated August 1980 WCAP 7116, "Point Beach Nuclear Power Plant Precautions, Limitations, and Set Points for Nuclear Steam Supply Systems", Page 8, dated 1011169 Westinghouse Correspondence WEP-06-23, "Input for Current Analysis of Record (RPSIESFAS)", dated March 25,2006 EQCK-BOST-001, "Checklist for Environmental Qualification Assessment of Boston Insulated Wire & Cable Company Bostrad 7 Insulated Single Shielded Twisted Pair, and Double Shielded Twisted Pair Cables", Rev. 1 DIT No, CRR-I&C-006, dated 2/17/2006, Regarding Elevated Tenlperature Impacts on Control Room Indicators Report F-C3694, '"Type Test Cable Qualification Program and Data for Nuclear Plant Designed Life Simulation through Sim~lltaneousExposure", prepared for the Okonite Co., dated 1/74

Calculation PBNP-IC-39 Revision 4 Page 27 of 117 PBNP klodification Request MR 98-002-C, "PPCS Changeover from Old to New PPCS", dated April 20,2005 NPC-28427, dated September 1, 1983, "Implenlentation ofRegulatory Guide 1.97 for Emergency Response Capability, Point Beach Nuclear Plant, Units 1 and 2" Passport Q-Basis Information for 1(2)PT-468,I (2)PT-469, l(2)PT-482, 1(2)PT-478, 1(2)PT-479, and 1(2)PT-483 (in "Attribuites" tab)

ASME Section VIII - 1967 Westinghouse Report WEPB-PCS-NAP-FL-001 -FS-02, WEPB Plant Computer Replacement Project Functional Design SpecificationDocument-Flow and Level Corrections", dated October 10,200 1 Westinghouse Repoi-t WEPB-PCS-NAP-IT-001 -FS-02, "WEPB Plant Computer Replacement Project Functional Design SpecificationDocument-Incore Thlocouples", dated October 08,2001 Passport Preventive Maintenance frequency check for Computer Analog to Digital Converters (located on DO80 panel under PMlD 17263)

Walkdown Calculation No. PBNP-IC-39, dated 7/17/06 (Attachment C)

NPC-36703, Seismic Evaluation Report, USNRC Generic Letter 87-02, US1 A-46 Resolution, Rev. 1, dated January 1996 PBF-2034, Rev. 74 - Control Room Log - Unit 1 PBF-2035, Rev. 74 - Control Room Log - Unit 2 TRM 3.7.3, "Steam Generator Pressure and Temperature (P/T) Limits" Rev. 1 B W Bostrad and Bostrad, "Flame Resistant Cables for Nuclear Power Plants",

Report No. B901, September 1969.

PBNP AR # 1057854, dated October 10,2006 NPC 2005-00414, EQ Field Verification Data, PAB and Turbine, dated June 28, 2005 Westinghouse Correspondence WEP-94-525, "Point Beach units 1 and 2 Reactor Protection & ESF Activation Analytical Limit Verification information Revision" dated February 1, 1994 Design Inforination Transmittal (DIT) CRR-I&C-014 dated 8/23/07, Supplement to Section 3.3.8 of PBNP Desigri Guide DG-I01 Rev 4, Metl~odologyto determine the Operability Limit

Calculation PBNP-IC-39 Revision 4 Page 28 of 117 C.64 Not Used G.65 FVEP-09-2 RPSIESFAS Safety Analysis Limit Setpoint Changes for the Point Beach Uprate Program, 8 January 2009.

G,& Wisconsin Electric Nuclear Power Business Unit Design and Installation Guidelines, DG-102, Rev. 0, "Instrument Scaling Methodology" 4.2 Drawings D.1 BD-6 Sh. 1, Block Diagram-Inst~wnentReactor Protection System Conlp, Steam Flow & Feedwater Flow-Loop A, Rev. 6 D.2 BD-7 Sh. 1 ,Block Diagrsun-Instrument Reactor Protection System Conlp, Steam Flow & Feedwater Flow-Loop B, Rev. 7 D.3 BD-18 JOB 10668, Block Diagram-Instrument Reactor Control Systenl Steam Generator Level -Loop A, Rev. 13 D.4 BD-I9 JOB 10668, Block Diagram-Instrument Reactor Control System Steam Generator Level -Loop B, Rev. 11 D.5 BD-6, Block Diagram-Instrument Reactor Protection System Comp, Steam Flow &

Feedwater FIow-Loop A, Rev. 5 D.6 BD-7, Block Diagram-Instrument Reactor Protection System Colnp, Steam Flow &

Feedwater Flow-Loop B, Rev. 5 D.7 BD-18 JOB 10665, Block Diagram-Instrument Reactor Control Systenl Steam Generator Level -Loop A, Rev. 10 D.8 BD-19 JOB 10665, Block Diagram-Instrument Reactor Control Systern Steam Generator Level -Loop B, Rev. 10 D.9 M-201, Sh. 1, "P&ID Main & Reheat Steam System Unit I?', Rev. 54 D.10 &I-2201, Sh. 1, "P&D Main & Reheat Steam System Unit 2", Rev. 49 D.ll 0082 Sh. 10, "Cable Spreading Room Air Conditioning System Rack C58", Rev.

9 D.12 P-107, Unit 1, "Main Steam Outside CTMT to I-IP T u b Control Valves and to Condenser 30.24 EB-1,24.18.16 EB-2 & 10HB-12", Rev. 12 D.13 P-108, Unit 1, "Main Steam Loop A&B From Steam Generator to Coiltainment Penetrations 130" EB-I Inside CTMTl", Rev. 5

Calculation PBNP-IC-39 Revision 4 Page 29 of 117 D.14 P-207, Unit 2, Sh.1, "Main Stearn Outside CTMT to HP Turb Control Valves 30",

24"EB-1 24", 18", 16"EB-2, 10"HB-12", Rev. 1 D. 15 P-208, Unit 2, "Main Steam Loop A&B From Steam Generator to Containment Penetrations (30EB-I)", Rev. 4 4.3 Procedures P. 1 l1CP 04.001E, "Reactor Protection and Safeguards Analog Racks Steam Pressure Reheling Calibration", Rev. 7 P.2 21CP 04.001E, "Reactor Protection and Safeguards ATlalog Racks Steam Pressure Refueling Calibration", Rev. 7 P.3 lICP 04.004-2, "Steam Generator Pressure Transmitter Outage Calibration", Rev.

7 P.4 Deleted per Rev. 2 of this Calculation.

P.5 IICP 02.001RD, "Reactor Protection and Engineered Safety Features Red Chamel Analog 92 Day SurveillanceTest", Rev. 11 P.6 IICP 02.001BL, "Reactor Protection and Engineered Safety Features Blue Channel Analog 92 Day Surveillance Test", Rev. 12 P.7 1ICP 02.001WH, "Reactor Protection and Engineered Safety Features White Channel Analog 92 Day Surveillance Test", Rev. 11 P.8 1ICP 02.001YL,, "Reactor Protection and Engineered Safety Features Yellow Channel Analog 92 Day Surveillance Test", Rev. 10 9 21CP 04.004-2, "Steam Generator Pressure Transmitter OLitage Calibration", Rev.

8 P. 10 Deleted per Rev. 2 of this Calculation.

P.ll 2ICP 02.001RD, Reactor Protection and Engineered Safety Features Red Channel Analog 92 Day Sux-veillance Test", Rev, 11 P.12 21CP 02,00lBL, "Reactor Protection and Engineered Safety Features Blue Cliam~el Analog 92 Day SurveillanceTest", Rev. 14 P.13 21CP 02.001WH, "Reactor Protection and Engineerecl Safety Features White Channel Analog 92 Day SurveillanceTest", Rev. 11

Calculation PBNP-IC-39 Revision 4 Page 30 of 117 21CP 02.001YL, "Reactor Protection and Engineered Safety Features Yellow Channel Analog 92 Day Surveillance Test", Rev. 12 ICP 11.95, "Installation of Seismnic/Environmemltal Qualified Transmitter 2PT-483 (MR IC-260)", Rev. 0 (available on ~llicrofilmn)

ICI 12, "Seleciion of M&TE for Field Calibrations", Rev. 8 ICP 11.39, "lnstallation of SeismicIE~~vironme~~tal Qualified Transmitter IPT-468 (MR 16-259)", Rev. 0 (available on microfilm)

ICP 11.40, "Installation of Seismic/Environmental Qualified Transmitter 1PT-469 (MR IC-259)", Rev. 0 (available on microfilm)

ICP 11.48, "lnstallation of Seismic/Environmental Qualified Transmitter 1F'T-478 (MR IC-259)", Rev. 0 (available on microfilm)

ICP 11.49, "Installation of Seisn~ic/EnviromentalQualified Tra~xnlitter1PT-479 (MR IC-259)", Rev. 0 (available on microfilm)

ICP 11.50, cLInstallation of Seismic/Enviroimental QualifiedTranslnitter 1PT-482 (MR IC-259)", Rev. 0 (available on nlicrofilm)

ICP 1 1.51, "Installation of Seismic/Environmental Qualified Transmitter 1PT-483 (MR IC-259)", Rev. 0 (available on microfilm)

ICP 11.90, "Installation of Seismic/Environmental Qualified Transmitter 2PT-468 (MR IC-260)", Rev. 0 (available on microfilm)

ICP 11.91, "Installation of Seismic/Environmental Qualified Transmitter 2PT-469 (MR IC-260)", Rev. 0 (available on microfilm)

ICP 11.93, "Installation of SeismicIEnvironmentalQualified Transmitter 2PT-478 (MR IC-260)", Rev. 0 (available on microfilm)

ICP 11.94, "Installation of Seismic/Environnlental Qualified Transmitter 2PT-479 (MR IC-260)", Rev. 0 (available on microfihn)

ICP 11.92, "Installation of Seismic/Environtnental Qualified Transmitter 2PT-482 (MR IC-260)", Rev, 0 (available on microfilm)

Fleet Procedure FP-E-RTC-02, "Equipment Classification - Q-List", Rev. I 1ICP 02.020BL) Rev. 10, "Post-Refileling Pre-Startup RPS and ESF Blue Channel Analog Surveillance Test" IICP 02.020RD, Rev. 11, "Post-Refileling Pre-Startup W S and ESF Red Cham~el Analog Surveillance Test" IICP 02.020WH, Rev. 10, "Post-Refueling Pre-Startup RPS and ESF White Channel AnaIog Surveillance Test"

Calculation PBNP-IC-39

~evision4 Page 3 1 of 117 P.32 lICP 02.020YL, Rev. 10, "Post-Refueling Pre-Startup RPS and ESF Yellow Channel Analog Surveillance Test" P.33 2ICP 02.020BL, Rev. 10, "Post-Weling Pre-Startup RPS and ESF Blue Channel Analog Surveillance Test" P.34 21CP 02.020RD, Rev. 10, "Post-Refbeling Pre-Startup RPS and ESF Red Channel Analog Surveillance Test" P.35 21CP 02.020W-I, Rev. 10, "Post-Reheling Pre-Startup RPS and ESF White Channel Analog Surveillance Test" P.36 2ICP 02.020YL, Rev. 10, "Post-Refbeling Pre-Startup RPS and ESF Yellow Channel Analog Surveillance Test7' 4.4 Vendor V.l Not Used.

V.2 Not Used.

V.3 Not Used.

V.4 Not Used.

V.5 Not Used.

V.6 Not Used.

Foxboro 66B series Electronic Consotrol Current Repeater, Data sheet GS 2A-2D 1 A, PBNP VTM #00623A4, Rev. 11 Foxboro 63U-B Duplex Alarm, PBNP VTM K00623A4, Rev. 11 Foxboro Specifications "Lead-Lag Module", PBNP VTM #00623A4, Rev. I1 Foxboro 6 10A Power Supply Specifications,PBNP VTM #00623A4, Rev. 11 Foxboro PSS-9-IBIA, "Model N-El 1 and N-El3 series Nuclear EIectronic Pressure Transmitters", VTM #00432, Rev. 21 Westinghouse Component Instruction Manual, Main Control Board - Part I, VTM

00132A, Rev. 25 Foxboro Corporate Product Specification CPS-0804, Rev. C, "Nuclear Electronic Gauge Pressure TransmittersN-El 1GM Series, Style A&B", VTM #00432, Rev. 21 Johnson Controls Temperature Composite Book 2, VTM #00309B, Rev. 05, dated 8/15/94 - T-4000 Series Pneumatic Room The~mostats(Tab - Thermostats &

Ther~nometers)

Calculation PBNP-IC-39 Revision 4 Page 32 of 117 V. 15 Combustion Engineering, Inc. 1485-ICE 1234, Rev. 2, "Ful~ctionalDesign Description for Seismic Safety Parameter Display System (SSPDS)", PBNP VTM

01209, Book 4 - Rev. 21 V.16 Westinghouse Model 44 Steam Generator (Unit I), VTM #00 104, Rev. 19 V.17 Westinghouse Model 47F Steam Generator (Unit 2), VTM #00109, Rev. 17 V. 18 Combustion Engineering, Inc. 1485-ICE 1239, Rev. 2, "Functional Design Description for Stifety Assessment System and Plant Process Computer System",

PBNP VTM #01209, Book 5, Rev. 21 V.19 Combustion Engineering, Inc., "SAS/PPCS Computer System - Volume 21 -

Manual Reinstated 5130103 Equipment in Plant", PBNP VTM #01055U, Revision 11, Tab F, "RTP7436110 Digital and Analog Loopback and Calibration Card."

4.5 Calculations C.l VECTM Calculation No. PBNP-IC-I 3, "Foxboro N-El I GM Transmitter Drift Calculation", Rev. 0 C.2 Not Used.

C.3 VECTM Calculation No. PBW-IC-07, "Westinghouse 252 Indicator Drift Calculation", Rev. 0 C.4 VECTRA Calculation No. PBNP-IC-10, "Foxboro 66RC-0LA LeadILag Drift CalcuIation", Rev. 0 C.5 Not Used.

C,6 EE 2005-0006, "Drift Calculations Evaluations", Rev. 0 C.7 Sargent & Lundy Calculation M-09334-357-HE.I, "Environmental Effects of High Energy Line Breaks Outside Containment7',Table 7-1, Rev. 3 C.8 Not Used.

C.9 Duke Calculation PBNP-IC-06, "Foxboro 63U-BC Bistable Drift Calculation",

Rev. 0 C.10 Not Used, C. 11 Calculation No. 97-0 140, "Revised Radiation Dose to Equipment Outside of Contai~lmentFollowing a Design Basis LOCA", Rev. 2 (2.12 CN-CM-01-70, "Point Beach SLB and Containment Response at 102% of 1524.5 MWt with FRV Failure", Rev. 0

Calculation PBNP-IC-39 Revision 4 Page 33 of 117 C.13 CN-TA-08-64, "Point Beach Units 1 and 2 (WPiWIS) Hot Full Power Stearnline Break - Core Response for the Extended Power Uprate (EPU)", Rev. 0

Calculation PBNP-IC-39 Revision 4 Page 34 of 117 5.0 ASSUMPTIONS 5.1 Validated Assumptions 5.1.1 NotUsed.

5.1.2 Not Used.

5.1.3 Not Used.

5.1.4 Not Used.

5.1.5 It is assumed that the maximum power supply effect for the I/I converters (isolators) is 1.0 % span and this effect is considered a random error, Basis: PBNP evaluation of A/R No. 141685 (CR 95-109) (Ref. G.7) indicates that the I/I Converter output fluctuates between 0.5 to 1.0 % due to the effect on the non-regulated portion of the internal 50 volt power supply in wbicll the VI co~~verter is connected. Furthermore, this error should be treated as random not a bias. Therefore, the maximum fluctuation of -+ 1 % is used in this calculation as the power supply effect for the UI Converter.

5.1.6 Not Used.

5.1.7 Not Used.

5.1.8 NotUsed.

5.1.9 It is assumed that the accuracy of the PPCS display loop is f0,51% of full scale.

This accuracy value applies to the loop from the PPCS analog input field terminations to the PPCS printed andlor display output devices. The accuracy value includes the temperature effect, power supply effect, humidity effect, radiation effect, seismic (vibration) effect, and drift over the entire PPCS normal operating range.

Basis: Per Reference (3.25, the PPCS replacement modification shall process inputs and outputs from existing UO devices. As such, the existing signal processing I/O isolation and signal conversion cards were not replaced as a result of Modification Request 98-002. References V.15 and V.18 document that the maximum total system enor for the old PPCS computer system, during norn~aloperating environments, from field terminations to the printed and/or display output shall be within 20.5% of the full scale (excluding errors before input of the analog input).

A review of all Westinghouse Plant Computer Replacement Reports revealed that the output values for all newly installed PPCS equipnlent (not including the existing UO devices discussed in the above paragraph) shall be within 0.1% of hand calculated results, with the following two exceptions:

Calculatio~lPBNP-IC-39 Revision 4 Page 35 of 117

1) For results based on polynomial curves, the output values shall be within 1.0% of hand calculated results (Reference G.5 1)

2) For results based on steam tables, the output values shall be within 0.5% of hand calculated results (References G.51 and G.52).

The PPCS points considered in this calculation display the Low Steam Line Pressure (in units of psig) based on a 10-50 mAdc input signal from the loop rack components.

Since the Low Steam Line Pressure loop is not a component of References (3.51 or (3.52, accuracy values associated with polynomial curves and steam tables are not applicable, and the accuracy of the newly installed PPCS equipment (not including the existing I/O devices) is considered to be 0.1%.

Therefore, to determine the overall PPCS system accuracy, the specified values of 0.1 % (for newly installed PPCS equipment) and 0.5% (for existing PPCS equipment) are combined using the SRSS methodology as follows:

PPCS a =d 0 . 5 + ~ 0.12 = -t0.51%

In accordance with Section 3.3.3.3 of Reference G. 1, if the manufacturer does not specify e~lvironmentalerrors associated wit11 the subject normal environmental accuracy ratings these effects are considered to be included in the specified accuracy ratings or are considered to be negligible.

Per Reference V.19, the PPCS analog-to-digital (AID) converters have a drift value of 50.01% for a period of 1-year. This value is not significant when compared to the much larger accuracy value of kO.5 1%. Per Reference G.53, the A/D converters are calibrated approximately every 36 weeks to eliminate any potential drifi. In addition these components historically never need to be calibrated because they do not drift. Therefore, the vendor specified drift value is considered negligible.

Per Section 3.3.3.15 of Reference G.1, in the absence of a vendor specified drifi value, it is typical for the device accuracy to be substituted in place of drift.

However, in the case of PPCS, considering an additional 50.51% for calculating the As-Found Tolerance would create a value large enough to allow PPCS degradation to go undetected. Conversely, by assuming that the drift value is included in the accuracy value, the As-Found Tolerance wouId remain tight enough to detect PPCS degradation prior to system failure. Therefore, the PPCS drift is conservatively encompassed by the F0.5 1% accuracy value.

5.1.10 It is assumed that the accuracy of the Leadllag Modules 1(2)PM-468A, 469A, 482A, 478A, 479A, and 483A is -t 0.2 nzA.

Basis: References (3.28 through G.39 are Instrument Traveler Sheets -

Refur5ishment Project for LeadLag Modules 1PM-468A, 469A7482A, 478A, 479A, and 483A, 2PM-468A, 469A, 482A, 478A, 479A, and 483A7and indicate that these modules were rehrbished in 1989 and 1990. Also in each of these

Calculation PBW-IC-39 Revision 4 Page 36 of 117 reports is attached a calibration report by Westinghouse Instrument Service Company, which indicates that the nlodules were calibrated to within the

+

acceptance tolerance or allowable error of 0.2 mA. The acceptance tolerance or

+

allowable error of 0.2 mA is, therefore, considered as the accuracy of the LeadJLagmodules.

5.1.1 1 It is assumed that the As-Left setting tolerances for the instruments evaluated in this calculation are as follows:

+ 0.20 mAdc for Sensor

+ 0.20 mhdc for PI Converter 2 0.002 Vdc for LeadILag Unit rir 0.002 Vdc for Bistable rir 0.80 mAdc for Control Room Indicator rt 7.0 psi for PPCS Indicator Basis: These As-Left Setting Tolerance values have historically provided acceptable instrument perfomance and consistency in the calibration program.

These As-Left setting tolerances are routinely achievable for the installed instruments, consistent wit11 safety limits and test equipment capability. They are currently used in practice at the station, and implemented by calibration procedures P.1 - P.3, P.5 - P.9, P.ll - P.14. As-Found setting tolerances are to be determined in this calculation.

5.1.12 It is assumed that the maximum environmental temperature of Control Room and Computer Room instrumentation is 120 OF.

Basis: Table 6-1 of WCAP-8587 (Ref. G.22) states that when the HVAC is non-safety related, the ~naximuinexpected temperature of 120 OF should be used. Since the Control Room and Coxnputer Room HVAC System chiller is not powered from an essential power bus, the Control Room and Computer Room W A C System is considered as a non-safety related system.

5.1.13 It is assumed that the maximum e~zvironnlentaloperating temperature for the existing installed PPCS system is 95 O F .

Basis: Reference G.47 (Attachments I and 5) identifies that the most temperature sensitive component of the new PPCS system is the non-ruggedized Sparc computer, which has an operating te~nperaturelimit of 95 O F . Note: the maximnurn temperature used for evaluating PPCS uncertainties is 85 OF, which is bounded by the PPCS operating temperature limit.

5.2 Unvalidated Assrrmptions

Calculation PBNP-IC-39 Revision 4 Page 37 of 1.17 6.0 DESIGN INPUTS 6.1 Loop Defi~iitious The loop components addressed in this calculation were identified in Refs. D.l through D.8. The loops associated with steam line pressure are shown below in Figure 6.2-1.

Section 6.3 lists the instruments addressed in this calculation. The relationship between the input and the output is provided for each component in Section 6.4. The instrument loops are the same for Unit 1 and Unit 2. Therefore, the setpoint and uncertainty calculations are applicable for both units.

6.2 Loop Block Diagram Power Supply Compensated Steam Flow Circuit*"

(PQ)

PPCS Point

Steam Line Pressure Current Converter Pressure Transmitter (PT) (PM) Indicator (PI) n LaadlLag Unit (PM)

Bistable (PC)

I Steatn Dump Control Va]ves*""

Low Alarm Safety Injection (Safeguard Actuation Logic)

Figure 6.2-1, Steam Line Pressure Instrument Loops P-468, P-469, P-478, P-479, P-482, & P-483

PPCS points are not applicable to loops P-468 and P-478.

- To Reactor Protection System (Uncertainty calculated in PBNP-IC-40 for Steam Plow/Feedwater Flow Mismatch)

- - Only by loops P-468 and P-478 input to Steam Dump Control valves.

6.3 Component Models and Tag Numbers The following table identifies each component shown in Figure 6.2-1 for the Steam Line Pressure instrument loops, and it provides the associated equipment information for use throughout this calculation.

Calculation PBNP-IC-39 Revision 4 Page 38 of 117 Table 6.3-1: Stean~Line Instrunlents Foxboro 66RC-Loop A : l(2)P-469 & 482 6.4 Range List The following table lists each component of the Steam Line Presswe Instrument loops and the respective input and output of each device (Ref. P.1 through P.3, P.5 through P.9, and P.11 through P.14).

Calculation PBNP-IC-39 Revision 4 Page 39 of 117 Table 6.4-1, Rarige List References P.3 and P.9 P.3 and P.9 P.1 and P.2 P.l and P.2 P.l and P.2 P. I and P.2

'10 - SO mAdc signal across a 10 C2 resistor 6.5 Cables Tbe Following table lists the Steam Line Pressure instrument cables and the relevant information reqnired to calculate the Insulation Resistance (LR)effects:

Calculation PBNP-IC-39 Revision 4 Page 40 of 117 Table 6.5-1, Steam Line Pressure Cables 6.6 Environmental Considerations The Steam Line Pressure channels P-468, P-469, P-482, P-478, P-479, and P-483, shown in the block diagram form in Figure 6.2-1, provide input to the Engineered Safety Features Actuation System (ESFAS) as well as alann and indication in the Control Room. These channeIs also provide indication at the PPCS. Four of the six channels also provide input to the Reactor Protection System (RPS), while two of the six channels are used for control of atmospheric steam dump valves.

The Point Beach commitment letter to the NRC (Ref. G.48) and Passport (Ref. G.49) identify steam generator pressure as a Reg. Guide 1,97 Type A and D variable. FSAR Table 7.6-1 (Ref. G.2) and the Q Basis codes 7,8, and 21 in Passport (Ref. G.49) identify steam generator pressure as a Category 1 variable (Note: PBNP is in the process of adding Reg. Guide 1.97 Category values into Passport). Q Basis codes 7, 8, and 21 are defined in Fleet Procedure FP-E-RTC-02 (Ref. P.28).

Steam Line Pressure has an associated Parametric Value which is monitored via the control room indication and recorded in operator logs to ensure that the TRM requirement is not violated (Ref. G.56 and G.57). Routine surveillance of instrumentation (in the Control Room) to determine Tech Spec compliance for a specific process is performed during normal plant operating conditions.

The PPCS indication is used for data monitoring and trending purposes. This function is non-safety related. This instrument loop is only required to operate during normal plant operating conditions.

Calculation PBNP-IC-39 Revision 4 Page41 of 117 6.6.1 Auxiliary Building The Steam Line Pressure transmitters are located in the Auxiliary Building (Ref.

P.3 and P.9)

The design temperatures for the Auxilia~yBuilding HVAC system per Ref. G.21 are 65°F during winter and 85°F during summer. The HVAC unit keeps the minimum nomal temperature above 65°F during the outage. Therefore, 65°F is to be used as the calibration temperature in this calculation.

FSAR Section 9.5 (Ref. G.2) states that the Auxiliary Building HVAC is non-safety related. From Table 6-1 of Reference G.22, the Auxiliary Building maximum temperature for normal conditions is 104°F. For a non-safety related HVAC system, the maximum temperature is 120°F due to a loss of air conditioning (Ref. G.22, Table 6-1). Since surveillance is only performed during normal plant operating conditions, for indication loops associated with Parametric values and PPCS indication, 104OF is used as the maximum temperature. For EOP nonnal conditions (Regulatory Guide 1.97 Categoly 1 variables), 120°F is used as the maximum temperature since the instmlentation is expected to operate under cornpromised environmental conditions caused by a loss of the HVAC Cooling Unit. For EOP accident conditions, the maximum Aux. Building accide~lt temperature is used.

All transmitters (l(2)PT-478, l(2)PT-479, and l(2)PT-483) for Loop B Steam Line Pressure are located in the Fan Room (Refs. P.3 and P.9). A steamline break (SLB) in the fan room could cause the temperature to reach 295 OF (Ref, C.7). The transmitters for Loop A Steam Line Pressure, 1(2)PT-468, 1(2)PT-469, and l(2)PT-482, are located in the spent fuel pool room of the Auxiliary Building (Ref.

P.3 and P.9). Per Reference C.7, a new HELB barrier was installed per MR 99-003 (Ref. G.27) to confine postulated HELB to the CCW RXBAT room and thereby prevent the steam from entering other areas of the Auxiliary Building.

Hence, the spent fuel pool room does not experience the environmental effects of a postulated HELB. However, the environmaltal conditions associated with a harsh environment in the fan room will be conservatively used for all the transmitters.

Transmitter cables in the Auxiliary Building could be exposed to a harsh environment.

The Auxiliary Building nonnal Ilumidity of 70% and radiation of 400 RADs (40 year dose) for normal conditions is documented in Ref. G.22. Calculatiol197-0140 (Ref. C. 11) revises post-LOCA radiation dose for outside containment due to changes in containment sump water volumes and changes in assumed water volumes injected from the Boric Acid Storage Tank. The Steam Line Pressure transmitters are not identified in Calculation No. 97-0140. Therefore, the post-LOCA environmental service conditions for outside containment following a LOCA are considered to be the same as the nornxal environment conditions as shown in Ref. G.22. Tenlperature conditions for accident considerations are documented in Ref. C.7.

Calculation PBNP-IC-39 Revision 4 Page 42 of 117 6.6.2 Control Room and Computer Room The rack components and control board indicators are located in the Control Room and Computer Rooin (Ref. P.1, P.2, P.5 through P.8, and P.ll through P. 14).

The Control Room HVAC System controls the temperature of the Control Room and the Computer Room at 75OF per Ref. G.21. Per FSAR Section 9.8.1 (Ref.

G.2), the temperature can vary f 10°F. This temperature variation is supported by the fact that the Johnson Controls T-4002-202 thermostat (Ref. D.11) in the Control Room is capable of controlling the room temperature (Ref.V.14) within these bounds. Therefore, the minin~umtemperat~u-eof 65°F is used as the calibration temperature for the components in the Control Room and Computer Room.

Since the Tech Spec surveillance (parametric) for control room indication and display monitoring is only perfo~inedduring normal plant operating conditions, 85 OF is used as the nlaximum temperature for these functions (Note, the maximum temperature limit for the PPCS is 95°F per Assumption 5.1.13). Per Assunlption 5.1.12, the maximum expected temperature is 120°F (loss of chiller). This maximum temperature of 120 OF is used for the Trip and EOP functions (safety-related and Regulatory Guide 1.97 Categoly 1 variable) since these functions may require the instrumentation to operate under compromised environmental conditions caused by a loss of the HVAC Cooling Unit.

The Control Room humidity of 50% and 95% (loss of chiller) is documented in Reference G.22. Section 11.6.2 (fifth paragraph) of FSAR (Ref. G.2) states that the Control Rooni is in Zone I and Table 11.6-1 states the rnasimtxnl dose rate in Zone X is 1.O nuemlhr.

Calculatioil PBNP-TC-39 Revision 4 Page 43 of 117 6.7 Existing Analyticalt Lirnit (AL), Field Trip Setpoint (FTSP), and Existing Allowable Value (AV)

The EPU Analytical Limit for Low Steam Line Pressure Safety Injection, discussed below, is 410 psia (Ref. 0.65 & C.f3), which is equivalent to 395.3 psig. The Field Trip Setpoint (FTSP) is 530 psig (Ref. P.5 th-oughP.8 and P. I 1 through P. 14). The Existing Allowable Value is 2 500 psig (Ref. G.24).

Calculation PBNP-IC-39 Revision 4 Page 44 of 117 I Field Trip setpoint I 530 psig The Iow steam line pressure safety injection is credited as a primay trip in two accident analyses (Reference G.43):

1. Core response to rupture of a steam pipe (with 2 loops in service)

2. Steam line break outside containment This actuation is also considered a backup trip for the following event, and a process limit is provided:

3. Steam line break inside containment Each of these thee situations will be discussed in turn, 6.7.1 Rupture of a steam pipe (with 2 loops in service)

The analytical limit provided is 335 psia (existing) & 410 psia (EPU). A process sensor hnctional time of 1.5 seconds is provided (Reference (3.43).

The steam line pressure transmitters are located outside containnlent. Since the steam line break could occur inside or outside of containment, it is possible for the transmitters "to experience adverse environmelltal conditions during a secondary side break." (Reference G.24) Therefore, post-accident environmental conditions should be considel-edwhen evaluating the setpoint with respect to this analytical limit.

Margin-to-Trip Westinghouse Calculation CN-TA-08-64 [Reference C.131 dete~minedthat noimal operational transients under EPU conditions would not cause a Low Steam Pressure Safety Injection Trip, with margin. Note that CN-TA-08-64 requires PBNP Units 1 & 2 to support a Low Steanlline Pressure - Safety Injection (SI) safety analysis setpoint of 410 psia (or higher) with an 18/2-second (or faster-responding) lead/lag on the steam pressure signal.

Refer to the calculation for the specific margin provided for different transients.

6.7.2 Steam line break outside contai~~rnent The analytical limit provided is 335 psia (existing) & 410 psia (EPU). A process sensor functional time of 16 seconds is provided (Reference G.43).

Calculation PBNP-JC-39 Revision 4 Page 45 of 117 This analysis should not be confused with the rupture of a steam pipe (with 2 loops in service) analysis, discussed invnediately above, which evaluates the effect of a large steam line break on the core. Unlilce the rupture of a steam pipe (with 2 loops in service) analysis-which demonstrates that a safety limit is not exceeded-the steanz line break outside containnlent is done to determine the mass and energy release for main steam line breaks for use as input to an environmental evaluation of safety-related electrical equipment outside containment.

The steam line pressure transmitters are located outside containment. Since the steam line break could occur inside or outside of contaiiment, it is possible for the transmitters "to experience adverse environmental conditions during a secondary side break." (Reference G.24) However, this limit 335 psia (existing) & 410 psia (EPU) is the same as the analytical limit for the rupture of a steam pipe (with 2 loops in service) case, discussed inmediately above. Since (1) the limit for the steam line break outside containment is the same as the analytical limit for the rupture of a stearn pipe (with 2 loops in service) and (2) the setpoint evaluation for the rupture of a steam pipe (with 2 loops in service) case will inco~poratethe larger instmnent uncertainties resulting from post-accident environmental conditions, the steam line break outside containment case is considered equivalent to the rupture of a steam pipe (with 2 loops in service) case.

Westinghouse Calculation CN-TA-08-64 [Reference C.131 determined that normal operational transients under EPU conditions would riot cause a Low Steam Pressure Safety Injection Trip, with margin. Note that CN-TA-08-64requires PBNP Units 1 & 2 to support a Low Stealdine Pressure - Safety Injection (SI) safety analysis setpoint of 410 psia (or higher) with an 18/2-second(or faster-responding) leadllag on the steam pressure signal.

Refer to the calculation for the specific margin provided for different transients.

6.7.3 Steam line break inside containment A process limit of 515 psia is provided. No process sensor functional time is provided (Reference G.43).

This analysis should not be confused with the rupture of a steam pipe (with 2 loops in service) analysis, discussed above, which evaluates the effect of a large steam line break on the core. Unlike the rupture of a steam pipe (with 2 loops in service) analysis-which demonstrates that core limits are not exceeded-the steam line break inside containment analysis denlonstrates that containment l i d s are not exceeded.

In the analysis of a steam line break inside containment (Reference C.12), all three automatic safety injection signals-high containment pressure, low pressurizer pressure, and low steam line pressure-were used as inputs. The results of the analysis show that safety injection is actuated by the high containnzent pressure safety injection signal. Since the low steam line pressure safety injection signal did not produce the safety injection-and, therefore, is not credited as the primary trip in this accident analysis--it functions as a backup trip. Hence, although the value of 515 psia was used as an input to the analysis, this value should not be used in determining the limiting trip setpoint (LTSP).

Calculation PBNP-IC-39 Revision 4 Page 46 of 117 However, because the signal fimctions as a backup trip and because the low steam line pressure safety injection setpoint has, starting with the originally specified setpoint (Reference G.42), always been set at a value 2 500 psig (Existing); 2520 psig (EPU), it is recommended that the field trip setpoint (FTSP) be maintained 2 500 psig(Existing); 2520 psig (EPU).

Westinghouse Calculation CN-TA-08-64 [Reference C.131 determined that normal operational transients under EPU conditions would not cause a Low Steam Pressure Safety Injection Trip, with margin. Note that CN-TA-08-64 requires PBNP Units 1 & 2 to support a Low Stearnline Pressure - Safety Injection (SI) safety analysis setpoint of 410 psia (or higher) with an 18/2-second (or faster-responding) leadlag on the steam pressure signal.

Refer to the calculation for the specific margin provided for different transients.

6.7.4 Summary The following analytical limit should be used in establishing the LTSP for low steam line pressure safety injection. The appropriate environmental conditions must be included in the setpoiat evaluation.

o Core response to rupture of a steam pipe (with 2 loops in service): 335 psia (existing)

& 410 psia (EPU), post-accident environment In addition, it is recommended that the FTSP be maintained 2 500 psig(Existing); 2520 psig (EPU).

Calculation PBNP-IC-39 Revision 4 Page 47 of 117 7.0 METHODOLOGY 7.1 Uncertainty Determination The uncertainties and loop errors are calculated in accordance with Point Beach Nuclear Plant's Instrument Setpoint Methodology, DG-101 (Ref. (3.1). This methodology uses the square root of the sum of the squares (SRSS) method to combine random and independent errors, and algebraic addition of non-random or bias errors. Clarifications to this methodology are noted below:

A) Treatment of 95/95 and 75/75 Values To convert 95/95 random uncertainty values to 75/75 uncertainty values (when applicable); this calculation uses the conversion factor specified in Section 3.3.3.13 of Reference G. 1. All individual instrument uncertainties are evaluated and shown as 95/95 values, and are combined under the Total Loop Error radical as such.

Conversion to a 75/75 value is performed after the random 95/95 TLE radical is computed.

B) Treatment of Significant Digits and Rounding This uncertainty calculation will adhere to the rules given below for the treatment of numerical results.

1. For values less than lo2,the rounding of discrete calculated instrument uncertainties (e.g. reference accuracy, temperature effect, etc,) should be performed such that the numerical value is restricted to three (3) or less digits shown to the right of the decimal point.

For example, an uncertainty calculated as 0.6847661 should be listed (and carried through the remainder of the calculation) as 0.685.

An uncertainty calculated as 53.235487 should be listed (and canied through the remainder of the calculation) as 53.235.

2. For values less than lo3, but greater than or equal to lo2, the rounding of discrete calculated instrument uncertainties (e.g. reference accuracy, temperature effect, etc.) should be perfomed such that the numerical value is restricted to two (2) or Iess digits shown to the right of the decimal point.

For example, an uncertainty calculated as 131.6539 should be listed (and canied through the remainder of the calculation) as 131.65.

3. For values greater than or equal to lo3,the rounding of discrete calculated instrument uncertainties (e.g. reference accuracy, temperature effect, etc.) should be performed such that the numerical value is restricted to one (1) or less digits shown to the right of the decimal point.

For example, an uncertainty calculated as 225 1.4533 should be listed (and carried through the remainder of the calculation) as 2251.5.

4. For Total Loop Uncertainties and Channel Check Tolerances, the calculated result should be rounded to the numerical precision that is readable on the

Calculation PBNP-IC-39 Revision 4 Page 48 of 117 associated loop indicator or recorder. If the loop of interest does not have an indicator or recorder, the Total Loop Error should be rounded to the numerical precision currently used in the associated calibration procedure for the end device in that loop (e.g. trip unit or alann unit).

5. For calibration tolerances, the calculated result should be rounded to the nutnerical precision cunently used in the associated calibration procedure.

These rules are intended to preserve a value's accuracy, while minimizing the retention of insignificant or meaningless digits. In all cases, the calculation preparer shall exercisejudgment when rounding and canying nutnerical values, to ensure that the values are kept practical with respect to the application of interest.

C) Determination of Channel Check Tolerance (CCT)

Per Section 3.3.8.7 of Reference (3.1, the CCT value is considered a 75/75 value.

I-Towever, convertiisg the CCT from 95/95 into a 75/75 value restricts the tolerance allowed for the indication loop devices and essentially makes it more difficult for the plant to meet their requirements. This approach is considered to be overly conservative. Therefore, this calculation will deternine CCT as a 95/95 value.

Although Reference G.l does not discuss the rounding techniques for CCT values, it is typical for tolerance values to be rounded down. This approach tightens the tolerance band, thus creating a conservative tolerance value. However, in the case of CCT, when a channel is determined non-operational, it is most likely to be found grossly out of tolerance, i.e., the difference between the chamel readings far surpasses the allowable CCT value. Therefore, in an effort to reduce the occurrence of false out of tolerance CCT readings, this calculation will round the CCT value up to the precision that is readable on the indication device.

D) Seismic Consideration for RPS/ESI?AS Trip Setpoints Seismic uncertainty must be evaluated as a contributor to overall loop error for some (not all) RPSIESFAS trip setpoints. The specific setpoints that require evaluation for seismic effects are those that are credited as primary trips for accidents/transients that could credibly occur as the result of a seismic event. These setpoints are found in the Seismic Evaluation Report, USNRC Generic Letter 87-02, US1 A-46 Resolution (NPC-36703) (Ref. G.55) and are listed below.

Calculatiorl PBNT-IC-39 Revision 4 Page 49 of 117 Table 7.1-1, Credible Accide~ltsITransientsDuring or Poilowir~ga SSE igh Pressurizer Pressure Trip setpoints not shown in the above table do not need to include a seismic uncertainty term because their trip function is not required during or follotving a seismic event.

Seismic versus Harsh Enviroment Seismic events do not create a hash environment. Therefore, seismic uncertainties and harsh environment uncertainties need not be combined in a single calculation of total loop error. If any of the above trips credited during a seismic event are also credited as primary trips duiing a LOCNMSLB that creates a harsh environment, then the uncertainty term (seismic or harsh environment) that results in the worst-case (largest) of the two TLEs should be applied for determining the limiting trip setpoint.

E) Seismic Consideration for EOP Setpoints The PBNP EOP setpoints are developed in accordance with the recornnlendations of the Westinghouse Owners Group Emergency Response Guidelines (ERGs). Tbe NRC reviews and approves the ERGs and plants with a Westingl~ouseNSSS are expected to follow them, documenting any plant-specific differences.

The ERG Executive Volunle provides guidance on the subject of instrument uncertainty as it relates to EOP setpoints. This guidance includes a discussion of the follo\villg components that contribute to the total instrument channel accuracy:

Process measureillent accuracy

Calculation PBNP-IC-39 Revision 4 Page 50 of 117 Primary element accuracy Sensor allowable deviation:

Reference accuracy Temperature effect Pressure effect Drift Rack allowable deviation:

Rack calibration accuracy Rack environmental effects Rack drift Comparator setting accuracy Environmental allowance due to the effects of being exposed to a high-energy line break:

Temperature Pressure Humidity Radiation Chemical spray Acceleration Vibration Reference leg heatup Indicator allowable deviation Nowhere in this detailed guidance is there any mention of a seismic term. (It should be noted that, as is clear from the context, the vibration and acceleration tetms mentioned in the above list refer o ~ d yto the vibration or acceleration associated with a high-energy line break.) That is, the ERG recommendations do not require that seismic effects be included in the determixlation of instrument uncertainty for EOP setpoitlts.

Therefore, seismic effects will not be considered in the instrument loop uncertainties used in determining EOP setpoints.

7.1.1 Sources of Uncertainty Per Ref, G. 1, the device uncertainties to be considered for normal envirom~ental conditions include the following:

Sensor Accuracy Sensor Drift Sensor M&TE Sensor Setting Tolerance Sensor Power Supply Effect Sensor Ten~peratureEffect Sensor Humidity Effect Sensor Radiation Effect

Calculatiot~PBNP-IC-39 Revision 4 Page 51 of 117 Sensor Seismic Effect Sensor Static Pressure Effect Sensor Overpressure Effect Current-to-Cunent Converter Accuracy Current-to-Current Converter Drift Current-to-Current Converter M&TE Current-to-Current Converter Setting Tolerance Current-to-Current Converter Power Supply Effect Current-to-Curre~~tConverter Temperature Effect Current-to-Current Converter Humidity Effect Current-to-Current Converter Radiation Effect Current-to-Current Converter Seismic Effect Lead/Lag Accuracy (LLa)

Lead/Lag Drift (LLd)

Leadnag M&TE (LLn?)

Leadnag Setting Tolerance (LLv)

LeadILag Power Supply Effect (LLP)

LeadILag Temperature Effect (LLt)

Leadnag Humidity Effect (LLh)

LeadILag Radiation Effect (LLr)

Leadnag Seismic Effect PPCS Accuracy (PPCSa)

PPCS Drift (PPCSd)

PPCS M&TE (PPCSm)

PPCS Setting Tolerance (PPCSv)

PPCS Power Supply Effect PPCSP)

PPCS Temperature Effect (PPCSt)

PPCS Humidity Effect (PPCSh)

PPCS Radiation Effect (PPCSr)

PPCS Seismic Effect (PPCSs)

PPCS Readability Effect (PPCSrea)

Indicator String Accuracy Indicator String Drift Indicator String M&TE Indicator String Setting Tolerance Indicator Power Supply Effect hdicator Temperature Effect Indicator Humidity Effect Micator Radiation Effect Indicator Seismic Effect Indicator Readability Effect Bistable Accuracy Bistable Diift Bistable MSrTE

Calcutation PBNP-IC-39 Revision 4 Page 52 of 117 Bistable Setting Tolerance Bistable Power Supply Effect Bistable Ten~peratu~e Effect Bistable Flumidity Effect Bistable Radiation Effect Bistable Seismic Effect Rack Accuracy Rack Drift Rack M&TE Rack Setting Tolerance Rack Power Supply Effect Rack Temperature Effect Rack Humidity Effect Rack Radiation Effect Rack Seisnlic Effect h~sulationResistance Effect (E)

Process Error The uncertainties will be calculated it1 percent of span and converted to the process units as required.

Per Section 3.3.3.13 of Ref. G. 1, the uncertainties listed above are considered 2 sigma (95% probability/95% confidence) unless otherwise specified.

7.1.2 Totar Loop Error Equation Summary (TLE)

This calculation detennines the uncel-tainties associated with the bistable, PPCS and indicator loops. Therefore, the Total Loop Ersor equation stated per Reference G.1 will be modified in order to calculate each function individually.

7.1.2.1 Total Bistable Loop Error (TLE,,)

Per Figure 6.2-1, the total loop error for the bistable contains the uncertainties for the loop sensor, raclc and bistable:

I+ ~m~ + sv2 + LL? + Bv2 +sp2 + LLp2 + BP2 +StR2 TLE,, = + Biases (Eq. 7.1.2.1)

+ LLt2 +~t~ + sha2 i-L L i ~~h~~ + srR2+ L L +~Br2 ~

I Where: TLEla= Total Accident Bistable Loop Error

Calculation PBNP-XC-39 Revision 4 Page 53 of 117 7.1.2.2 Total PPCS Loop Error (TLEZn)

Per Figure 6,2-I, the total loop error for the PPCS contains the uncertaillties for the loop sensor, rack and PPCS:

s a 2 + I/1a2 + P P C S ~+ s~d 2 + IfId2 + P P C S + ~ srn2

~

+ I/Irn2 + PPcsrn2 + s v 2 + J/1v2 + PPCSV~+ sp2+ Ihp2 TLE,, = I- pPcsp2 + stn12+ I/1t2 + PPCst2 + s h n 2+ I/1h2 + P P C S ~ +Biases ~ (Eq. 7.1.2.2)

+ srn2+ 1fi2+ P P C S ~+ s~s 2 + I/b2 + PPCSS~+ Sspe,, 2 2

+ Sopen where:

TL&, = Total Nonnal PPCS Loop Error 7.1.2.3 Total Indicator Loop Error (TLESn,TLE3,,

Per Figure 6.2-1, the total loop error for the indicator contaiils the uncertainties for the loop sensor, rack and indicator:

s a 2 -iv1a2

- + 1a2 + s d 2 + y1d2 + 1d2 + srn2

-t yxm2 + 1m2 + s v 2 + I/1v2 + 1v2 + sp2+ NP2 TLE,,, = -;- + S S ~i,- ~ + 1t2 + s h n 2+ I/Ih2 + Ih2 + Biases I/1t2 (Eq. 7.1.2.3-1)

+ srn2 + I / I ~+ 1r2

~ + s s 2 + X / I S ~+ 1s2 + Sspe, 2

+ Sope, 2 where:

TLE3, = Total Nonnal Indicator Loop Error TLE -

I+ 1m2 + sv2 + V I V ~+ 1v2 + sp2+ np2+ lP2+ sta2

+I/I~ ~ + s h a 2 + I I I +~ f~i 2 +ssa2+y1r2 + b2

+1t2

+Biases (Eq. 7.1.2.3-2) where:

TLE3, = Total Accident Indicator Loop Error

CalcuIatiot~PBNP-IC-39 Revision 4 Page 54 of 117 where:

TLE3p = Total Parametric Loop Error 7.1.3 As-Found Tolerance Equation Summary Per Section 3.3.8.6 of Reference G.l, the As-Found Tolerances are calculated independently for each of the loop components. The following equations will be used.

7.1.3.1 Sensor As-Pound Tolerance ( S M )

The Acceptable As-Found Tolerance for the sensor (SAF) is calculated with the following equation:

sAF=i -I\ (Eq. 7.1.3.1)

Where:

Sv = Sensor Setting Tolerance Sd = Sensor Drift Sm = Sensor M&TE en-or 7.1.3.2 Current-to-Current Converter As-Found Tolerance (1/IA3?)

The Acceptable As-Found Tolerance for the VI convetter (YL4F)is calculated with the following equation:

I/IAF = f ,/I/Iv2 + I/1d2 + 1/1rn2 (Eq. 7.1.3.2)

Where:

UIv = Cunent-to-CurrentConverter Setting Tolerance UId = Cunent-to-Current DriR I/Im = Current-to-Cul-rentM&TE error

Calculatio~lPBNP-IC-39 Revision 4 Page 55 of 117 7.1.3.3 Lead/Lag As-Found Toterailce (LLAF)

The Acceptable As-Found Tolerance for the leadlag unit (LLAF) is calculated with the following equation:

LLAF = + JT..L~' + L L ~ '+ L L ~ ' (Eq. 7.1.3.3)

Where:

LLv = Lead/Lag Setting Tolerance LLd = Lead/Lag Drift LLm = Lead/Lag M&TE error 7.1.3.4 Indicator As-Found Tolerance (M)

The Acceptable As-Found Tolerance for the indicator (L4F) is calculated with the following equation:

IAF = f JiFTCFZF (Eq. 7.1 -3.4)

Where:

fv = Indicator Setting Tolerance Id = Indicator Drifi Irn = Indicator M&TE error 7.1.3.5 PPCS As-Found Tolerance (PPCSAF)

The Acceptable As-Found Tolerance for the computer (PPCSm) is calculated with the following equation:

PPCSAF = i JPPCSV' + PPCS~'+ P P C S ~ ~ (Eq. 7.1.3.5)

Where:

PPCSv = PPCS Setting Tolerance PPCSd = PPCS Drift PPCSm = PPCS M&TE error 7.1.3.6 Bistable As-Found Tolerance (BAF)

Per Figure 6.2-1, the bistable outputs to the SI logic and a11 alarm.

Therefore, the As-Found Tolerance must be applied to both setpoints. The Acceptable As-Found Tolerance for the bistable (BAJ?) is calculated with the following equation:

BAF = f JBV' + E!dz + ~m~ (Eq. 7.1.3.6)

Where:

Calculation PBNP-IC-39 Revision 4 Page 56 of 117 Bv = Bistable Setting Tolerance Bd = Bistable Drift Brn = Bistable M&TE error 7.1.4 As-Left Tolerance Equation Su~nmary Per Section 3.3.8.6 of Reference (3.1, the As-Left Tolerances are calculated independently for the rack components, sensor and indicator.

7.1.4.1 Sensor As-Left Tolerance (SAL)

The Acceptable As-Left Tolerance for the sensor (SAL) is equal to its setting tolerance:

SAL = rt Sv Where:

Sv = Sensor Setting ~ o l i r a n c e 7.1.4.2 Current-to-Current Converter As-Left Tolerance (IJIAL,)

The Acceptable As-Left Tolerance for the Yf converter is equal to its setting tolerance:

VIAL = rfr YIv Where:

YIv = Current-to-CurrentConverter Setting Tolerance 7.1.4.3 LeadiLag Unit As-Left Tolerauce (LLAL)

The Acceptable As-Left Tolerance for the leadlag unit is equal to its setting tolerance:

LLAL = rt LLv Where:

LLv = LeadLag Setting Tolerance

Calculation PBNP-IC-39 Revision 4 Page 57 of I I7 7.1.4.4 Indicator As-Left Tolerance (I&)

The Acceptable As-Left Tolerance for the indicator (IAL)is equal to its setting tolerance:

IAL=+Iv Where:

Iv = Indicator Setting Tolerance 7.1.4.5 PPCS As-Left Tolerance (PPCSAL)

The Acceptable As-Left Tolerance for the PPCS (PPCSAL) is equal to its setting tolerance:

PPCSAL = PPCSv Where:

PPCSv = PPCS Setting Tolerance 7.1.4.6 Bistable As-Left Tolerance (BAL)

Per Figure 6.2-1, the bistable outputs to the SI logic and an alarm.

Therefore, the As-Left Tolerance must be applied to both setpoints. The Acceptable As-Left Tolerance for the bistable (BAL) is equal to its setting tolerance:

BAL = t.Bv Where:

Bv = Bistable Setting Tolerance 7.1.5 Parametric Values The paarnetric values are limits for process parameters to validate cursent limits in operator logs to ensure Tech Spec limits are not violated. Tbe parametric values are calculated as follows:

Parametric Values = (Tech Spec Limits -b TLE) (Eq. 7.1.5-1)

Where:

TLE = The 75/75 value of the Total Loop Error for the indicator loop as required in the Operator Daily Logsheet The direction (positive or negative) ofthe TLE applied to the Tech Spec limit is determined by the process. For example, an increasing process requires that the negative TLE be applied to the Tech Spec limit to establish the parametric value.

Calculation PBNP-XC-39 Revision 4 Page 55 of 117 7.1.6 Operability Limit (OL) Equation Summary Per Section 3.3.8.2 of Reference (3.63, the Operability Lirnit (OL) is defined as a calculated linliting value that the As-Found bistable setpoint is allowed to have during a Technical Specification surveillance Channel Operational Test (COT),

beyond which the instrument channel is considered inoperable and corrective action must be taken. Two OLs are calculated, one on each side of the FTSP as-left tolerance band, incorporating a calculated 3-sigma ( 3 ~ drift

) value. A channel found drifting beyond its 30 drift value is considered to be operating abnormally (i.e., is inoperable).

Per Section 3.3.8.4 of Refereilce (3.63, the OL on each side of the FTSP is calculated as follows:

OL' = FTSP + [RAL2 + Rd3,23 ' (Eq. 7.1.6-1)

OL- = FTSP - [RAL2 + +d3;] ' (Eq. 7.1.6-2)

Where:

the FTSP is expressed in percent of span OL' is the Operability Limit above the FTSP OL' is the Operability Linlit below the FTSP RAL is the rack as-left tolerance (typically the bistable tolerance)

Rd3, is the 30 rack drift value determined as follows:

The rack drift value (Rdz,) is the 2-sigma drift value for components checked during the COT, typically the bistable dxift.

Scaling Per Reference (3.66, for an instru~neiltwith a linear input and output relationship, the output signal can be determined as follows:

(Eq. 7.1.7-1)

(Eq. 7.1.7-2)

(Eq. 7.1.7-3)

Where:

x = Process value variable, a known input (psig)

XI = Process value variable, at 0 % span (psig)

X2 = Process value variable, at 100 % span (psig)

Y = Analog value variable, an unknown output (inAdc)

YI = Analog value at 0 % span (mddc)

Y2 = Analog value at 100 % span (nlAdc) 111 = Slope, or gain of the hnction, scale factor

Calculatior~PBNP-IC-39 Revision 4 Page 59 of 117 7.2 Drift Considerations The drift values established in Reference C.1 are utilized for the transmitters, Reference C.3 utilized for the indicators, Reference C.4 utilized for the leadllag unit, and Reference C.9 utilized for the bistables.

Use of the aforementioned drift value (as design input to this calculation) is based on justification provided by Engineering Evaluation 2005-0006 (Ref. C.6). This evaluation reviews the station's M&TE and M&TE control programs, based on requirements imposed by the methodology used to prepare instrument setpoint and uncertainty calculations for the station (Ref. G.1). The evaluation condudes that the station's M&TE and M&TE control programs have remained equivalent or improved since the drift calculations were initially prepared, and therefore, renders the driit calculations acceptable for use in current (present-day) calculation revisions performed for the station.

7.3 Channel Check Tolerarrce Equation Summary (CCT)

Per Reference G.l, the CCT represents the maximum expected deviation between channel indications that monitor the same plant process parameter. The CCT is dete~nlinedfor instrument loops that require a qualitative assessnlent of channel behavior during operation.

This assessment involves an observed comparison of the channel indicationlstatus.

When perfo~minga channel check, it is generally assumed that the instrumellt loops are redundant to each other, i.e., measuring the same parameter. A channel check involves a conlparison of two indications independent of the number of redundant loops using the reference accuracy (a), setting tolerance (v), drift (d), and readability (rea) of each device.

Per Section 7.1, the CCT value is rounded up to the numerical precision that is readable on the associated loop indicator and is considered a 95/95 value. The CCT is determined using the SRSS method shown below:

( ~ a , '+ma,' +1a12+sv12+I/Ivl2 +-1v12 +sd12+I/Idl2 7.4 Setpoint Calculations Per Section 3.3.8.4 of Reference G.l, when a setpoint is approached from one direction and the uncertainties are normally distributed, a reduction factor of 1.645h.96 = 0.839 may be applied to a 95/95 (95% probability at a 95% confidence level) TLE. The reduction factor should only be applied to the rand0111portion of the TLE that has been statistically derived using the SRSS method. Therefore, this calculation deviates from the methodology of DG-I01 (Reference G. l), and separates the TLE into random and bias terms in order to apply the reduction factor solely to the random portion of the TLE.

Calculation PBNP-IC-39 Revision 4 Page 60 of 117 For a process increasing toward the Analytical Limit, the calculated Limiting Trip Setpoint is as follows:

For a process decreasing toward the Analytical Limit, the calculated Limiting Trip Setpoint is as follows:

7.5 Process Error Calculation The process bias uncertainty will be calculated by calculating the differential pressure corresponding to head coll-ection at the design temperature (68OF) and comparing it to the differential pressure at the maximunl temperature during accident condition (298°F).

dP Error = [(Av

dPjlead-comcrion) I PSI

100% (Equation 7.6-1)

Where:

dP Error = Differentia1 Pressure Process Error Av = Specific Gravity Difference &om 68OF to 298OF dPhead-conection = Differential Pressure of the Head Correction PS = Process Span

Calculation PBNP-IC-39 Revision 4 Page 61 of 117 8.0 BODY OF CALCULATIONS 8.1 Device Uncertainty Analysis This section will deterxnine all applicable uncertainties for the devices that comprise the Steam Line Pressure Instrunlentation Loop shown in Section 6.

From Ref, G.1 (Section 3.3.4.3), the drift values calculated from As-Found/As-Left instru~nentcalibration data normally include the euor effects under llosmal conditions of drift, accuracy, power supply, plant vibration, calibration temperature, normal radiation, normal humidity, M&TE used for calibration, and instrument readability. If it is determined that the calibration conditions are indicative of the normal operating conditions, the environmental effects need not be included separately. A11 device unce~taintyternls are considered random and independent unless othenvise noted.

8.1.1 Sensor Accuracy (Sa)

Ref. C.1 has determined the l~istoricaldrift values for the N-El 1GM transmitter.

Per Section 3.3.4.3 of Ref. G.1, when drift error values have been statistically derived from As-Found/&-Left calibration data, the Sensor Accuracy of the transmitter is included in the instnunent drift value. Therefore, Sa = f 0.000% span 8.1.2 Sensor Drift (Sd)

Ref. C.1 has determined historical drift values for the N-El 1GM transmitter. The 95%/95% sensor drift value for a two year interval is conservatively used based on 18 months channel calibration and 25% Tech Spec Allowance.

Sd = 4 0.518% span Bias = rt 0.000% span 8.1.3 Sensor M&TE (Sm)

Ref. C.1 has determined the historical drift values for the WE11 GM transnlitter.

Per Section 3.3.4.3 of Ref. G.l, when drift enor values have been statistically derived from As-Found/As-Lefc calibration data, the Sensor M&TE of the transmittel-is included in the instrument drift value. Therefore, Srn = If: 0.000% span

Page 62 of 117 8.1.4 Sensor Setting Tolerance (Sv)

Per Ref. P.3, P.9 and Assumption 5.1.1 1, the sensor setting tolerance is 1:0.20 mAdc, and the calibrated span is 40 nlAdc. Therefore, Sv = (sensor setting tolerancelcalibrated span)

100%

Sv = (k 0.20 mAdc / 40 mAdc)

100%

Sv = +0.500% span 8.1.5 Sensor Power Supply Effect (Sp)

Ref. (2.1 has determined the histosical drift values for the N-El IGM transmitter.

Per Section 3.3.4.3 of Ref. G.1, when drift error values have been statistically derived from As-Found/As-Left calibration data, the Sensor Power Supply Effect of the transmitter is included in the instrument drift value. Therefore, 8.1.6 Sensor Temperature Effect (St)

The Steam Line Pressuse transmitters are Foxboro Model N-El 1GM. Per Ref.

G.61, the tsansmitter limits are 200 and 2000 psi. Per Ref. V.13, this corresponds to capsule code E. Therefore, the upper span limit of 2000 psi is used. Per References P.3 and P.9, the calibrated span is 1400 psig, which is 70% of the upper span limit. Reference V. 13 specifies a zero shift span error of rt: 1.5 % per 100 OF for a calibi-atedspan between 50% and 80% of lnax span (or upper span litnit) and a span error of rt: 1.25 % per 100 OF. These errors are combined using the SRSS method per Ref. G. 1.

From Section 6.6.1, the transmitters are located in the Aux. Building where the normal ambient temperature range is 65 to 120 OF. As stated in Section 6.6.1, the transmitters are evaluated for the two different normal enviromnental conditions:

65°F to 104OF and 65OF to 120°F. These esrors are combined using the SRSS method per Reference G. 1.

Zero Shifr error (St.ZsRo)at normal parametric conditions (65 to 104°F)

St-ZERO = -?1(1.5%span/lOO°F) * (104 - 65°F)

St-ZERO = 't 0.585% span Span Shift error (St.spAN)at normal parametric conditions (65 to 104OF)

St-SPAN = rt: (1.25% span/lOO°F) * (104 - 65OF)

StSpAN= f 0.458% span Sensor Temperature Effect at nonnal parametric conditions (65 to 104°F) (Stni)

Calculation PBNP-IC-39 Revision 4 Page 63 of 1 17 Stnl = k [(S~.ZERO)~ f (s~-SPAN)~]"~

Stnl = + [(0.585% span12-I- (0.488% span)2]"

Stnl = rt 0.762% span Zero Shift error (St-zeRo)at normal EOP conditions (65 to 120°F)

St.ZEw = rt (1.5% span/lOO°F) * (120 - 65°F)

St-ZERO = f 0.825% span Span Shift error (StSPAN) at normal EOP conditions (65 to 120°F)

Sensor Temperature Effect at normal EOP conditions (Sta)

=f 1.074OA span Ref, V. 13 defix~estemperature above 250°F within the LOCA/HELB profile. Per Section 6.6.1, the sensor accident temperature is 298OF. Per Ref. V.13, the maximum output shift for a LOCA/I4ELB is rt8.0%. Therefore, St, = 1- 8.000% span 8.1.7 Sensor Hunudity Effect (Sh,, Sh,)

Per Section 3.3.3.20 of Reference (3.1, changes in dmbient lluinidity have a negligible effect on the uncertainty of the instruments used in this calculation.

Sh, = t- 0.000% span Sb, = rt 0.000% span 8.1.8 Sensor Radiation Effect (Sr,, Sr,)

Ref. C.1 has determined the historical drift values for the N-El 1GM transmitter.

Per Section 3.3.4.3 of Ref. G.1, when drift error values have been statistically derived from As-Found/As-Left calibration data, the Sensor Radiation Effect of the transmitter during normal conditions is included in the instrument drift value.

Therefore, Sr, = rfI 0.000% span Per Section 6.6, the Aux. Building does not experience an increase in radiation from normal during an accident. As a result, the Sensor Radiation Effect of the transmitter under accident conditions is the same under normal conditions, Therefore, sI-, = rt 0.000% span

Calculatiori PBNP-IC-39 Revision 4 Page 64 of 117 8.1.9 Sensor Seismic Effect (Ss)

Ref. C.l has deteimined the histo~icaldrift values for the N-El 1GM transmitter.

Per Section 3.3.4.3 of Ref. G. 1, when drift error values have been statistically derived from As-FoundIAs-Left calibration data, tbe effect of normal vibration is included in the instnunent drift value. Therefore, Ss, = rt 0.000% span Steam Line Pressure is not a trip variable included in Table 7.1-1, and therefore, the trip function is not required during and following a seismic event.

Furthe~more,per Section 3.3.3.10 of Reference G.1, it is assumed that instrumentationwill be recalibrated prior to any subsequent accident, thus negating any permanent shift that may have occurred due to the seismic event. Therefore, Ss, = + 0.000% span It should also be noted that seismic effects will not be included 111the Total Loop Error for EOP indication. Per section 7.1(E), seisnlic effects do not contribute to the total instrument channel accuracy when determining EOP setpoints. Therefore, this effect is equal to zero in the Total Loop Error radical for EOP Irldication (TLE3, in Section 8.3.4).

8.1.10 Sensor Static Pressure Effect (Sspe,, Sspe,)

Per Reference G.1, Section 3.3.4.1 1, static pressure effects due to change in process pressure only apply to differential pressure instruments in direct contact with the process. Therefore, Sspe, = k 0.000% span Sspe, = f 0.000% span 8.1.11 Sensor Overpressure Effect (Sope,, Sope,)

The Steam Line Pressure transmitters are rated for a maximum over-range pressui-e of 3000 psig (Ref. V. 13). Per References V.16 and V.17, the mechanical design condition (shell design) for the secondary side of the steam generators is 1085 psig.

From ASME Section VIII (Ref. G.501, the allowable overpressure is 10% of the design (or 108.5 psig). Therefore, the maximum pressure inside the vessel is 1193.5 psig. The maximum over-range pressure is rated well above the Steam Generator design pressure (1 193.5 psig) and the calibrated span of 1400 psig (Ref.

P.3 and P.9). Therefore, the sensor overpressure effect is considered negligible.

Sope, = k 0.000% span Sope, = + 0.000% span

CalcuIaiiol~PBNP-IC-39 Revision 4 Page 65 of 117 8.1.12 Current-to-Current Converter Accuracy (Ma)

Per Ref, V.7, the VI Converter accuracy is +0.5% of output span.

TIIa = & 0.500% span 8.1.33 Current-to-Current Converter Drift (11111)

Drift is unspecified by the vendor (V.7). Per Section 3.3.3.15 of Reference G.l, in the absence of an appropriate drift analysis and when drift is unspecified by the vendor, the instment's accuracy is used to represent the instrument drift over the entire calibrationperiod.

IlId = .4 0.500% span 8.1.14 Current-to-Current Converter M&TE (IIIm)

Per References P.1 and P.2, the I/I Converters are calibrated using a multimeter appropriate for 0.1-0.5 Vdc at the Converter input (due to a 10 St loop series test point resistor), and a multimeter appropriate for 10-50 ~nAdcat the output. The M&TE effect is due to the multinleters used at the UI Converter input and output.

According to calibration procedure ICI 12 (Ref. P. 16), the following M&TE are capable of performing this measurement.

HP 34401A multimeter at VI b u t (6.5 digit display, 1.0 Vdc range) w n ~ ~ +

= (0.0040 % reading -k 0.0007 % range)

R.-b,~e = -t- [0.0040 % (0.5 Vdc) + 0.0007 % (1.0 Vdc)]

RAmre = + 0.000027 Vdc U s t d =0 RDIIIIC = + 0.000001 Vdc From Sectio113.3.4.4 of Reference G.1, M&TE uncertainty is calculated using the following equation:

m HP = id0.000027' + o2 + 0.000001~=i-0.000027 Vdc Fluke 45 multimeter at 111Input (5 digit display, 3.0 Vdc range)

RA,,,I, = uncertainty " nlax reading u m t e = + 0.025% reading

0,5 Vdc RAn~te = rf: 0.000125 Vdc U s t d =0 RQnre = + 2 DGTS

0.0001 Vdc m m ~ e = + 0.0002 Vdc

Calculatioli PBNP-IC-39 Revision 4 Page 66 of 117 From Section 3.3.4.4 of Reference (3.1, M&TE uncertainty is calculated using the following equation:

Fluke 884214 multimeter at 111Input (6.5 digit display, 2.0 Vdc r a n ~ e )

Umte = uncertainty

max reading U m t e = f 0.003% reading

0.5 Vdc Unite = rt: 0.000015 Vdc RAstd =0 RDmte = f 2 DGTS

0.00001 Vdc RDmte = rt 0.00002 Vdc From Section 3.3.4.4 of Reference G.1, M&TE uncertainty is calculated using the following equation:

m,,, = fd0.000015~ 0' + + 0.00002~=f0.000025 Vdc The uncertainty of Fluke 45 (n14 = f 0.000236 Vdc) is used as the bounding input M&TE because it is the less acc~irateof the two M&TE.

Co~lvertingto % span, mg = f (0.000236 Vdc 1 0.4 Vdc)

100 % span Fluke 45 multimeter at I/I Output (fast resolution, 100 mAdc range):

R.&nte = uncertainty

max reading RAnlte = + 0.05% reading " 50 mAdc Umte = f 0.025 ~nAdc R&,d =0 m n t e "

= f 3 DGTS 0.001 mAdc RDtnte = + 0.003 mAdc From Section 3.3.4.4 of Reference G.1, M&TE uncertainty is calculated using the following equation:

nu =f Juzrnte c R . A ~+. IR~ D ~ , ~ ~ ~

Calculation PBNP-IC-39 Revision 4 Page 67 of 1 17 rrtl5 = k 4 0 . 0 2 5 ~+ o2 + 0.003~= + 0.025 mAdc HP 34401A multimeter at I71 Output (6.5 digit display. 100 mAdc range)

RA,nte = rt: (0.050 % reading + 0.005 % range)

MI,,&= i [0.050 % (50 d d c ) -t 0.005 % (100 ~nAdc)]

Mmte = rt 0.030 mAdc W i d =0 RDm = rt: 0.0001 mAdc Fronz Section 3.3.4.4 of Reference (3.1, M&TE uncertainty is calculated using the following equation:

+

The uncertainty of HP 34401A (nzHp= 0.030 mAdc) is used as the bounding output M&TE because it is the less accurate of the two M&TE.

Converting to % span, l n ~ p = k(0.030 mAdc / 40 mAdc) " 100% span The total M&TE uncertainty for the calibration of the Z/I Converter is calculated using the nlultiple M&TE equation given in Section 3.3.4.4 of Reference G.1:

2 2

~i~m = iJm, +m,,

UIm = 1: 0.095 % span

Calculation PBNP-IC-39 Revision 4 Page 65 of 117 8.1.15 Current-to-Current Converter Setting Tolerance (IIIv)

Per Ref. P. I, P.2 and Assunlption 5.1.11, the I/I Converter setting tolerance is k0.20 mAdc and the calibration span is 40 mAdc.

LlIv = calibration tolerance * (100% span / calibrated span)

I/Iv = If:0.20 mhdc " (100% span 140 mAdc)

I/Iv = F 0,5009'0span 8.1.1G Current-towcurrentConverter Power Supply Effect (X/Ip)

From Reference (3.7, the VI Converter has been shown to expc~iencea random power supply effect caused by the non-regulated portion of the internal 50-volt power supply. This primarily affects only the I/I Converters or isolators.

Therefore, per Assumption 5.1.5, UIp = F 1000% span 8.1.17 Current-to-Current Converter Temperature Effect (IIXt)

As stated in Section 6.6.2, the VI Converter is located in the Control Room, which has a bounding ambient temperature range of 65 OF to 120 OF. Froin vendor information (Ref. V.7), the X/I Converter has a normal operating range of 40°F to 120 OF with no associated temperature effect. Therefore, the temperature effect is considered negligible.

8.1.18 Current-towcurrent Converter Humidity Effect (I/&)

Per Section 3.3.3.20 of Reference G. I , changes in ambient humidity have a negligible effect on the uncertainty of the instruments used in this calculation.

I/Ih = f 0.000% span

Calculation PBNP-IC-39 Revisioxl4 Page 69 of 117 8.1.19 Current-to-Current Converter Radiation Effect (Ulr)

The 111Converter is located in the Control Room where the radiation is minimal.

Furthermore, per Section 3.3.3.21 of Reference G.1, normal radiation errors are considered sinall with I-espect to other uncertainties and can be calibrated out.

Therefore, the UX Converter radiatio~leffect is considered negligible.

I/Ir = i:0.000% span 8.1.20 Current-to-Current Converter Seisnzic Effect (111s)

There is no seisnlic effect provided by the vei~dorfor the I/I converter (Ref. V.7).

Per Section 3.3.4.10 of Ref. G. 1, the effects of nonnal seismic or vibration events for non-mechanical instlumentation are considered zero unless vendor or industry experience indicates otherwise. Therefore, UIs = f 0.000% span 8.1.21 LeadILag Accuracy &La)

Per Assunlption 5.1.10, the accuracy of the LeadfLagModules is f 0.2 mA and the calibration span is 40 mAdc. Therefore, LLa = (module accuracy/calibrated span)

100%

LLa = (4: 0.2 mA/40 mA)

100% span LLa = f 0.500% span 8.1.22 Lead/Lag Drift &Ld)

Reference V.9 does not provide a drift specification for the Lead/Lag Module. Per Section 3.3.3.15 of Reference G.l, when drift is not specified by the vendor, the accuracy of the component is used as the drift for the entire calibration period.

Therefore, LLd =f 0.500% span Per Ref. P. 1 and P.2, the Stemn Line Pressure Leadnag Modules are calibrated using a nlultimeter appropriate for 0.1-0.5 Vdc (due to a 10 C2 loop series test poillt resistor) at the module input and output. The M&TE effect is due to the lnultimeter used at the module input and output. According to calibration procedure ICI- 12 (Ref. P.16), Fluke 45 and 8842A are capable of perfomGng this measurement.

Calculation PBNP-IC-39 Revision 4 Page 70 of 117 For the Fluke 45 multimeter (5 digit disglay, 3 Vdc range)

RAnItc *

= uncertainty nlax reading RAInte = + 0.025% reading

0.5 Vdc RAn>to = rf: 0.000125 Vdc RA,,<l =0 R%ti = 2.2DGTS

0.0001 Vdc RQnte = rt 0.0002 Vdc From Section 3.3.4.4 of Reference G. 1, M&TE uncertainty is calculated using the following equation:

m = ~ J R A+~ +

R A, ~~~ .~ RD2,nte O

LLm4 = uncertainty * (100% span / calibrated span)

LLm5 = rt 0.000236 Vdc * (100% span / 0.4 Vdc)

LLw5 = i 0.059% span For the Fluke 8842A multinleter (6.5 digit display, 2 Vdc range)

RA,I,I, = uncertaifity

max reading

%I, = 4 0.003% reading

0.5 Vdc Mnuc +

= 0.000015 Vdc RA,t,i =O RDmte = rt: 2 DGTS

0.00001 Vdc RQnt, = 4 0.00002 Vdc From Section 3.3.4.4 of Rekrence G. 1, M&TE uncertainty is calculated using the following equation:

m = *,/RA2,nte+RA2s* +RD2.,te L L I I ~ ~= (uncertainty

~ ~ ~ / calibrated span)

100% span LLmsn2 = rt (0.000025 Vdc / 0.4 Vdc)

100%

LLms8d:! = rt 0.00625% span The worst case and bounding input and output M&TE error is LLms = i0.059%

span.

The total M&TE uncertainty for the calibration of the Leadnag Module is calculated using the multiple M&TE equation given in Section 3.3.4.4 of Reference G.l:

M = + m,2 +m22 +..,.m, 2 LLm = & ,/0.059' + 0.059' = f 0.083% span LLm = + 0.083% span

Calculation PBNP-IC-39 Revision 4 Page 71 of 117 8.1.24 LeadILag Setting Tolerance (LLv)

Per Ref. P , l , P.2 and Assumption 5.1.I 7, the LeadlLag Module tolerance is zk 0.002 Vdc, and the calibrated span is 0.40 Vdc. Therefore, LLv = (module setting tolerance/calibrated span)

100%

LLv *

= (*0.002 VdciO.4 Vdc) 100% span LLv = 40.500% span 8.1.25 Lead/Lag Power Supply Effect (LLp)

The vendor does not provide any power supply effect for the LeadLag Modules (Ref. V.9). Section 3.3,3.16 of Ref. G.1 states that industry experience with simiiar devices should be considered in the absence of vendor data. Review of similar devices from the same vendor (Foxboro Spec 200 modules such as the 63U-BC Bistable) does not provide power supply effect information. Therefore, the LeadLag Modules power supply effect is considered negligible and included in the drift effect.

LLp = 4 0.000% span 8.1.26 Lead/Lag Temperature Effect (LLt)

The vendor has not provided a temperature effect specification for the Lead/Lag Modules (Ref. V.9). Per Refs P.1 and P.2, the LeadlLag Modules are located in the Control Room, which is a temperature-controlled area and subject to a mild environment under all plant conditions. From vendor information in Reference V.9, the Lead/Lag Modules are specifred to operate in an ambient temperature range of 40 to 120 O F . Therefore, the temperature effect is considered negligible and included in the drift effect.

LLL = f0.000% span 8.1.27 Lead/Lag Humidity Effect (LLh)

Per Section 3.3.3.20 of Reference G.1, changes in ambient humidity have a negligible effect on the uncertainty of the instruments used in this calculation.

Therefore, LLh = f0.000% span

Calculation PBNP-IC-39 Revision 4 Page 72 of 1I7 8.1.28 LeadJLag Radiation Effect (LLE-)

The LeadILag Modules are located in the Control Roonl, which has a nlild environment under all plant conditions. Per Section 3.3.3.21 of Reference G.1, radiation errors are considered to be included in the drift error. Therefore, LLr = tt 0.000% span 8.1.29 LeadLag Seismic Effect (LLs)

There is no seismic effect provided by the vendor for the LeadILag Modules (Ref.

V.9). Per Section 3.3,4.10 of Ref. G.1, the effects of seismic or vibration events for non-mechanical instrumentation are considered zero unless vendor or industry experience indicates otherwise. Therefore, LLs = rt 0.000% span 8.1.30 Bistable Accitracy @a)

Reference C.9 has detennined the historical driA values for Foxboro Model 63U-BC Bistables. Per Reference G.1, when &ift error values have been statistically derived from As-Found/As-Left calibration data, the accuracy of the Bistables is included in the instrument drift value. Therefore, Ba = f 0.000% span 8.1.31 Bistable Drift (Bd)

Reference C.9 has detennined the historical drift values for Foxboro Model 63U-BC Bistables. Per References P.5 through P.8 and P.ll through P.14, the containment pressure Bistables are calibrated every 92 days or quarterly. Per Table 8.2 of Reference C.9, the quarterly 95% probability/95% confidence Bistable Drift value is:

Bd = rtr 0.212% span 8.1.32 Bistable M&TE (I3m)

Reference C.9 has determined the historical drift values for Foxboro Model 63U-BC BistabIes. Per Section 3.3.4.3 of Ref. G.1, when d~ifterror values have been statistically derived from As-FoundIAs-Left calibration data, the MStTE Effect of the bistable is included in the instrument drift value. Therefore, Brn = f 0.000% span

Calculation PBNP-XC-39 Revision 4 Page 73 of 117 8.1.33 Bistable Setting Tolerance @v)

Per References P.5 through P.8 and P.1 I through P.14, the bistable setting tolerance is t-0.002 Vdc / - 0.000 Vdc and the calibrated span is 0.4 Vdc. Per

+

Assumption 5.1.1 1, this value is a symmetrical 0.002 Vdc (Note, the signal is in Vdc due to a 10 SZ resistor connected across the calibration point). Therefore, Bv = t- 0.0020 Vdc Bv = t- uncertainty * (100% span / calibrated span)

Bv = t0.0020 Vdc * (100% span / 0.40 Vdc)

Bv =f 0.500% span 8.1.34 Bistable Power Supply Effect @p)

Reference C.9 has determined the historical drift values for Foxboro Model 63U-BC Bistables. Per Section 3.3.4.3 of Ref. G.1, when drift error values have been statistically derived from As-FoundAs-Left calibration data, the Power Supply Effect of the bistable is included in the instrument drift value. Therefore, Bp = f 0.000% span 8.1.35 Bistable Ten~peratu~e Effect (Bt)

The bistable is located in the Control Room where the temperature is controlled by the W A C system. Per Reference G.21, the change in temperature for the Control Room goes from 65 O F to 120 OF. Since the vendor does not provide any temperature effect information (Ref. V.8), it is expected that the temperature inside the Control Room is well within the operating range of the bistable, and therefore there is no temperature effect.

Bt = i.0.000% span

Calculation PBNP-XC-39 Revision 4 Page 74 of 117 8.1.36 Bistable Humidity Effect (B11)

Per Section 3.3.3.20 of Reference G. 1, changes in ambient humidity have a negligible effect on the uncertainty of the instrunzents used in this calculation.

Bh = f 0.000% span 8.1.37 Bistable Radiation Effect (Br)

The bistable is located in the Control Room where the radiation is minimal.

Furthermore, per Section 3.3.3.21 of Reference G.1, nonnal radiation errors are considered small with respect to other uncertainties and can be calibrated out.

Therefore, the bistable radiation effect is considered negligible.

Br = f0.000% span 8.1.38 Bistable Seismic Effect (Bs)

There is no seismic effect provided by the vendor for the bistable (Ref. V.8). Per Section 3.3.4.10 of Ref. G.l, the effects of normal seismic or vibration events for non-mechanical instrumentation are considered zero unless vendor or industry experience indicates otherwise. Therefore, Bs = f 0.000% span 8.1.39 PPCS Accuracy (PPCSa)

Per Assumption 5.1.9, the PPCS accuracy is f0.510% span. Therefore, PPCSa = f 0.51O0A span 8.1.40 PPCS Drift (PPCSd)

Per Assun~ption5.1.9, the drift for the PPCS is irlcluded in the accuracy term.

Therefore, PPCScl = rt 0.000% spau

Calculation PBNP-IC-39 Revision 4 Page 75 of 117 8.1.41 PPCS M&TE (PPCSm)

Per Reference P.l and P.2, the Steam Line Pressuse PPCS is calibrated with a multirneter capable of measuring 10-50 mAdc on the input and reading the PPCS display at the output (PPCS Readability Effect is accounted for in Section 8.1.48).

According to calibration procedure ICI 12 (Reference P.16), the following M&TE are capable of performing this measurement.

FIuke 45 muItimeter (fast resolution, 5 digit display, 100 mAdc ran~e):

W,ntc= uncertainty

max reading RA,,, = rtO.O5% reading

50 mAdc RA,, = +0.025 mAdc M,,l =0 RD,,, = 3: 3 DGTS

0.001 d d c

+

RD,,, = 0.003 mAdc From Section 3.3.4.4 of Reference G.1, M&TE uncertainty is calculated using the following equation:

m,, = t 40.025~ + o2 + 0.003~= -i:0.025 m ~ d c HP 3440IA tnultimeter (6.5 digit display, 100 lnAdc range) m,n,e = rt (0.050 % reading + 0.005 % range)

Mmt, = k [0.050 % (50 t d d c ) 0.005 % (100 mAdc)]

RA,,i, = 3: 0.030 mAdc Mstd =0 Rhlt, = f 0.0001 nAdc From Section 3.3,4.4 of Reference G.l, M&TE uncertainty is calculated using the following equation:

rn,, = 3:d0.0302 + 0' + 0.0001~=-t0.030 m ~ d c The uncertainty of HP 34401A (mHp= 5 0.030 mAdc) is used as the bounding input M&TE because it is the less accurate of the two M&TE.

Converting to % span, mnp = rt (0.030 rnAdc / 40 mAdc) " 100 % span m~p = rt 0,075 % span Therefore, the M&TE uncertainty for the calibration of the PPCS is:

Calculation PBNP-IC-39 Revision 4 Page 76 of 117 PPCSln = f 0.075 O/O span 8.1.42 PPCS Setting Tolerance (PPCSv)

Per Ref. P.l, P.2 and Assumption 5.1.1 1, PPCS setting tolerance is k7.0 psi.

PPCSv *

= calibration tolerance (1 00% span / calibrated span)

PPCSv *

= Ifi 7.0 psi (100% span /I400 psi)

PPCSv = -t 0.500% span 8.1.43 PPCS Power Supply Effect (PPCSp)

Per Assunlption 5.1.9, the power supply effect for the PPCS is included in the accuracy term. Therefore, PPCSp = It 0.000% span 8.1.44 PPCS Temperature Effect (PPCSt)

Per Assunlption 5.1.9, the temperature effect for the PPCS is included in the accuracy tern, Therefore, PPCSt = +- 0.000% span 8.1.45 PPCS Humidity Effect (PPCSh)

Per Assumption 5.1.9, the humidity effect for the PPCS is included in the accuracy term. Therefore, PPCSb = 3- 0.000% span 8.1.46 PPCS Radiation Effect (PPCSr)

Per Assunlption 5.1.9, the radiation effect for the PPCS is included in the accuracy term. Therefore, PPCSr = f0.000% span

Calculation PBNP-IC-39 Revision 4 Page 77 of 117 8.1.47 PPCS Seislnic Effect (PPCSs)

Per Assumption 5.1 -9, the seismic effect for the PPCS is included in the accuracy teml. Therefore, PPCSs, = t- 0.000% span PPCSs, = rfr. 0.000% span 8.1.48 PPCS Readability Effect (PPCSrea)

Per References P.l and P.2, the PPCS display has 1 decimal place and the span is 1400 psi. Per Reference G.1, Section 3.3.5.3, the readability esror for a digital display is the least significant digit. Therefore, PPCSrea = k (reading error / calibrated span)

100%

PPCSrea = f.(0.1 psi / 1400 psi)

100%

PPCSrea = f 0.007% span 8.1.49 Indicator Accuracy (Ia)

Ref. C.3 has determined the historical drift values for the Indicator. Per Section 3.3.4.3 of Ref G.l, when drift error values have been statistically derived from As-Found/As-Left calibration data, the accuracy of the indicator is included in the drift value. ThereIore, Ia = 0.000% span 8.1.50 Indicator Drift (Id)

Per Ref. P.1 and P.2, the indicators are Westinghouse HX-252 and they are calibrated individually. Reference C.3 is the As-Found/As-Left drift analysis for Westinghouse HX-252 indicators that are either string calibrated with Poxboro 66BC-0 Isolators or individually calibrated. Although the drift analysis perfonued in Reference C.3 does not include the As-Found/As-Left data of the Steanz Line Pressure indicator, the individually calibrated Westinghouse HX-252 Indicator therein is considered representative of the indicators experienced at PBNP (Ref.

C.6). Since the Steam Line Pressure indicators are calibrated evety 1S montl~s (Ref. P.l and P.2), the 100%, 2-year 95%/95% dt-ift value is conservatively used.

Therefore, d = + 1.028% span Bias = rt:0.000% span

Calcdation PBM-IC-39 Revision 4 Page 78 of 117 8.1.51 Indicator M&TE (Im)

Ref. C.3 has determined the historical drift values for the indicator. Per Section 3.3.4.3 of Ref. G.1, when drift erxor values have been statistically derived from As-FoundIAs-Left calibration data, the M&TE effect of the indicator is included in the drift value. Therefore, Im = 0.000% span 8.1.52 Indicator Setting Tolerance (Iv)

+

Per Ref. P. 1, P.2 and Assumption 5.1.I 1, the setting tolerance is 0.8 mAdc, and the calibrated span is 40 mA. Therefore, Iv = -t- (setting tolerance / calibrated span) " 100%

Iv = k(0.8 rnAI4OmA)

100%

Iv = f2.000% span 8.1.53 Indicator Power Supply Effect (Ip)

Ref. C.3 has determined the historical drift values for the indicator. Per Section 3.3.4.3 of Ref. G.1, when drift error values have been statistically derived &on1As-FoundIAs-Left calibration data, the power supply effect of the indicator is included in the drift value. Therefore, Ip = f 0.000% span 8.1.54 Indicator Temperature Effect (It)

Per Section 6.6.2, the indicators are rack components located in the Control Room, which is environmentally controlled between 65 OF to 120 O F . Per Reference V. 12, the vendor does not provide temperature effects for the indicators. Therefore, the temperature effect is considered included in the ifidicator drift.

It = f 0.000% span 8.1.55 Indicator Humidity Effect (Ih)

Per Section 3.3.3-20of Reference G. 1, changes in ambient humidity have a negligible effect on the uncertainty of the instruments used in this calculation.

Therefore, Ih = 0.000% span

CaIculation PBNP-XC-39 Revision 4 Page 79 of 117 8.1.56 Indicator Radiation Effect (Ir)

Per Section 6.6.2, the indicators are rack componalts located in the Control Room, which is a radiological mild environment. Referelm C.3 has determined the historical dlift values for the indicator. Per Section 3.3.4.3 of Ref. G.l, when dlift error values have been statistically derived from As-FoundfAs-Leftcalibration data, the radiation effect of the indicator is included in the drift value. Therefore, Ir = f 0.000% span 8.1.57 Indicator Seismic Effect (Is)

There is no seismic effect provided by the vendor for the indicators (Ref. V.12).

Per Section 3.3.4.10 of Ref. (3.1, the effects of seisnlic or vibration events are considered zero unless vendor or industry experience indicates otherwise. Vendor infomation shows that the indicators are seismically qualified (Ref. V.12), with no additional seismic effect specified. Therefore, 1s = Itr: 0.000% span 8.1.58 Indicator Readabilily Effect ( h a )

Ref. C.3 has dete~minedthe historical drift values for the indicator. Per Ref. G.1, when drift error values have been statistically derived from As-FoundlAs-Left calibration data, the readability effect of the indicator is included in the drift value.

Therefore, Irea = f O.OOOOh span 8.1.59 Process Error (PE)

According to Ref. G.54, the elevation of the Loop A Steam Line Pressure transmitters for Units 1 & 2 is approximately 50' 1.25". The eIevation of the Loop B Steam Line Pressure transmitters for Units 1 & 2 is approximately 70' 1.25". Per Reference D.12 - D.15, the top of the water leg elevation is 88'-0" for both Loops A and B. Under normal operating conditions, the density difference due to a change in temperatures results in an error so small that it would be rounded off per section 7.1 (B), Therefore, only the PE due to abnormal temperature is determined.

Loop A sensing lines are located in a non-harsh area and are exposed to normal temperature conditions. The density changes of the Loop B instrunlents, which are located in a SLB area, are considered to be greater and will be conservatively used to detexmine the process error applicable for both loops.

The minimum height from the top of water Ieg to transmitters (Loop B) is:

hn - Top of water leg elevation - Loop B Transmitter Height

CalcuIatioll PBW-IC-39 Revision 4 Page SO of 117 Converting fiom height to pressure under normal atmospheric conditioil at 68 OF:

psi per foot of water = 0.4335 psYftH20 (Ref. (3.5, Table 2-3)

Loop B dP,,,,~o,c,io, = 17.896 ft

0.4335 psi/ftHzO

= 7.758 psi Per Ref. G.5, the specific volume of compressed water @ 500 psig (AL):

specific gravity @ 68 OF - (V @ 68 OF) (VI)

- 0.0160234 / 0.0160234

- I .o specific gravity @ 298 O F - (V@ 68 OF) / ( ~ 2 )

- 0.0160234 / 0.0173978

- 0.921 Difference of specific gravity (Av) from 68 OF to 298 OF is 0.079.

Using Equation 7.6-1, dP Error = [(Av

dPhead conection)

/PSI

100%

Loop B PE = [(0.079

7.758 psi) 1 1400 psi]

100%

PE = 0.044 %

As the temperature increases, the density of the static leg will decrease. Therefore, PE will be a negative error and treated as a bias.

PE = - 0.044% span

Calculatioti PBNP-IC-39 Revision 4 Page 81 of 117 8.1.60 Insulation Resistance Effect (IR)

Leakage cu~rentsduring accident conditions (HELB) could cause a reduction irt insulation resista~~ce of the cables and splices for the Steam Line Pressure Ioop configuration. The instrument loop is a 10 to 50 mAdc current Ioop with a Foxboro N-El I GM transmitter. If the leakage current develops in the loop due to cable insulation degradation, the path is represented as a shunt resistance in parallel to the transmitter. The Steam Line Pressure circuit can Be represented as follows:

Junction Box Splices Cahle 1

Power Supply Figure 8.1.60-1, Signal Trallsmission Component The signal transmission components (transmitte~s)are subject to IR degradation during an accident.

The equivalent circuit schematic representing the above wiring diagram showing the IR leakage path is shown below:

Figure 8.1.60-2 Equivalent Circuit Schematic Where:

1, = Device output current at point of interest IRSPL = IR value of the splice at the transmitter junction box.

IRCBL = IR value of the signal cable.

v, = Power Supply Re = Load resistor

Caiculation PBNP-IC-39 Revision 4 Page 82 of 117 The above circuit (Figure 8.1.60-2) can be sinlplified as follows:

~c $ ~ e 4-Figure 8.1.60-3, Simplified Circuit

where,

- 1 1 =-------- 1

+-------

R, IRSPL IRCBL From Section 6.6.1, only tra~lsmittersl(2)PT-478, l(2)PT-479, and l(2)PT-483 are located in the fan room. Therefore, only these transmitters are exposed to accident conditions and contribute IR effects. For conservatism, the IR effect is determined from the maximum cable length of each transmitter from Ref. G. 16. From table 6.5-1, the applicable transmitters have four different types of cables as analyzed below.

e Installation procedures (Ref P.15 and P.17 - P.27) indicate that the splices at the transmitterjunction box use Raychem Type ACSF-N Sleeves. Tyco Electronics (Raychein) Report EDR-5336 (Ref. G.40) evaluates Raychenl Type WCSF-N Splices and determines that the IR value is 2.5 x 10% at 500 Vdc. Therefore, s There are four different types of cable used for the loops evaluated in this calculation, each with differing IR values. Each cable type is evaluated and the worst case is used as the total IR effect. From Appendix G of Ref. G.1, the following equation is used to determine the effective resistance when an lR value is given for a test length of cable.

Ri = (R)(LIR)1 LC (Eq. 8.1.60-2) where:

Rt = Effective Resistance (IRCBL)

Calculatiotl PBNP-XC-39 Revision 4 Page 83 of 117 IR = cable 1R value per unit length LIR = vendor test cable lengt11 LC = installed cable length The results calculated according to cable length and manufacturer are presented in Table 8.1.60-1.

Reference G.23 provides the equation for the Rockbestos cable insulation resistance as follows.

The equation is evaluated at the maximum accident steam line break temperature (T) of 298 OF (421 Icelvin). Per Ref. (3.23, the insulation diameter (D) is 0.096 inches; 16 AWG wire has a conductor diameter (d) of 0.056 inches. The cable length for each transmitter is substituted as 'x' into the equation. From Table 6.5-1, the only applicable Rockbestos cable comes from 2PT-483 and is 375 ft long.

Therefore, 15

e-o.079*421

log( 0.096 in. ) M a forlOOOft 0.056 in. 1 / 375 fi IRCBLROck = 8.95 x 10~52for lOOOft This method of calculation corresponds only to the cable coming from 2PT-483 and the value can be found in Table 8.1.60-1 below.

Information from Table 6.5-1 and the manufacturer IR values below are substituted into Eq 8.1.60-2 to calculate the specific JR value of each of the remaining cables.

The results are presented below in Table 8.1.60-1.

From Reference G.41, the lowest cable insulation resistance for Brand Rex cables nleasured during testing at 3 17 OF (this bounds the maximum accident temperature of 298 OF) for specimen 5-2 is 3.2 x lo7 SZ for 30 ft of test cable. Therefore, IRBR = 3.2 x lo7Q for 30 R.

From Reference G.46, the lowest cable insulation resistance for Okonite cables measured during LOCA testing at 3 15 OF (this bounds the maximum accident temperature of 298 OF) for specimen 4B is 1.9x106i-2 for 20 feet of cable (Section 4.2 of Ref. G.46). Therefore, ll&,,i,,= 1.9 x lo6 SZ for 20 ft From References (3.44 and (3.59, the results of a simulated LOCA test for BIW cables at 316 OF (this bounds the maximum accident temperature of 298 OF) show that the lowest measured IR value is 8.0 x lo7SZ for 10 k of cable. Therefore,

Calculation PBNP-KC-39 Revision 4 Page 54 of 117 Rnrw= 8.0 x lo7 R for 10 ft From the above table, the worst case IR effect is for the cable from IPT-479.

Therefore, r Per Reference V.10, the load of the power supply must be at least 600R.

Otherwise, the potentiometer must be adjusted to account for the cun'ent. From Figure 6.2-1 and 6.2-2, the only loop loads on the power supply are the Current Converter and the Leadlag Module; the transmitter load is considered 0 R (Ref. V.11). The Current Converter Ioad is 100 R (Ref. V.7) and the LeadILag Module load is 200 R (Ref. V.9). As a result, the voltage in the transmitter loop is 84 1?: 2 Vdc (Ref V.10). Therefore, VS = 56 Vdc s Per References V. 11, the minimum transmitter load around the loop is 600R.

As previously stated, 300 Ll from the loop components and the other 300 SZ coines from the potentiometer adjustment on the power supply. Therefore, Substituting the above values, together with the mininluln input current of 10 mA (,formaxinzum error) to Equation I , Appendix G of Reference G.1:

Substituting in Equation 2, Appendix G of Reference G. I to obtain the error in percent span.

Calculation PBNP-IC-39 Revision 4 Page 85 of 117 IR, = 1.808 %.span The error due to reduction in insulation resistance for accident conditions is a positive bias. This error is only applicable to accident conditions.

IR, = 1.808 % span

CaIcuIation PBNP-IC-39 Revision 4 Page 86 of 117 8.2 Device Uncertainty Summary 8.2.1 Sensor Uncertainties 8.2.2 Current-to-Current Converter Uncertainties

Calculation PBNP-XC-39 Revision 4 Page 57 of 1 17 8.2.3 Leadbag Module Uncertainties 8.2.4 Bistable Uncertainties

Calculation PBNP-IC-39 Revision 4 Page 88 of 117 8.2.5 PPCS Uncertainties 8.2.6 Indicator Uncertainties 8.2.7 Process Considerations

Calculation PBNP-IC-39 Revision 4 Page 89 of 117 8.3 Total Loop Error 8.3.1 Accident Total Bistable Loop Error (TLEI,)

Low Steam Line Pressure Safety Injectio~~ is a decreasing setpoint. Per Section 7.4, it is only necessary to calculate the positive TLE with separate random and bias portions.

Using Eq. 7.1.2.1,

~L~r-ra,' = + 8.097% spao (95195)

From Section 8, insulation resistance is the only positive bias. Therefore, TLEia-bias = Biases* = IR TLEI,-hiad = + 1.808% span f95/95)

Calculation PBNP-IC-39 Revision 4 Page 90 of 117 8.3.2 Normal Total PPCS Loop Error (TLE2,,)

Using equation 7.1.2.2, TLE2, = +1.837% span (95195)

Converting to process units, TLE2, =(rt1.837% span) * (1400psi)ll00%

TLEZn = f 25.72 psi (95195)

Convert to 75/75 error:

e r r ~ r ~=~(1, ,,1511.96)

~

errorg5,gs (Section 3.3.3.13 of Ref. G.l)

TLEl=(1.1511.96)"f1.837%span=rt1.078%span TLEz,, = f 1.078 % span (75175)

Converting to process units, TILE2, = (+I .078% span) * (1400 psi)/l00%

TLE2, = t- 15.09 psi (75175)

Calculation PBNP-IC-39 Revision 4 Page 91 of 117 8.3.3 Normal Total Indicator Loop Error for EOP Input (TILE3,,)

Using Equation 7.1.2.3-1, s a 2 + H a 2 + 1a2 + s d 2 + u1d2 + 1d2 + srn2

+ y h 2 -I-1m2 -t- s v 2 + v1v2 4 1v2 + sP2+ 1hp2 TLE,, = + rP2 +st ,22 + I11t2 -t- 1t2 + s b n 2 +7/111~+ Ih2 + Bias 1 + srn2+ I / L +~1r2 ~ + s s 2 + YI~' + 1s' + Sspe, 2

+ Sope, 2 TLE3, = 52.913% span Converting to process units, TL,E3,, = (92.913% span) * (1400 psi)/100%

TLE3, = rl: 40.78 psi (95195 )

Convert to 75/75 error:

= (1.1511 .96) * (Section 3.3.3.13 of Ref. G.l)

TLE3,=(1.15/1.96) ""k2.913%span=+1.710% span TLE3, = 51.710% span (75175)

Converting to process units, TLE3,, = (&1.710% span) * (1400 psi)l100%

TLE3, = k 23.94 psi (75175)

...............+........*..*......................................................*......*...

Calculation PBNP-IC-39 Revision 4 Page 92 of I17 8.3.4 Accident Total Indicator Loop Error For EOP Input (TLE3,)

The reduction factor to convert a 95/95 variable to a 75/75 variable should only be applied to the random portion of the TLE that has been statistically derived using the SRSS method. Therefore, the random and bias portions of the TLE are separate.

Using Equation 7.1.2.3-2, TLE3a-rdm 8.446% span

= ZIZ (95195)

From Section 8, insulation resistance is the only positive bias and the process error is the only negative bias. Therefore,

'I'~E3a-bia: = Biases* =IR

~ ~ ~ 3 a - b i a s f = + 1.808% span (95195)

TLE3a-biai = Biases- = PE TLE3a-bias- -

= 0.044% span (9SI95)

To determine the total TLE, the random and bias portions of like sign are combined as follows:

TLE~,*= TLE~,.,~,;+ TLE3,-biasC = + 8.446% span + 1.808% span TLE~; = + 10.254% span TLE3,- = TLE3a-rdlil' 4- TLE3a.biai =- 8.446% span - 0.044% span

Calculation PBNP-IC-39 Revision 4 Page 93 of 117 Converting to process units, TZ;E~: = (TLE~,")" PS TLE~ ~

= (+10.254%)

1400 psi = 4-143.56 psi TLE3,' = (TLE3,')

PS TLE3a- = (-8.490%)

1400 psi = -118.86 psi Therefore, TLE3r = 1-143.56psi, -118,86 psi Convert to a 75/75 enor:

E r r ~ r=~[(I , ~ ~

e r r ~ r - r d r n ~ 4-

~ .15/1.96) ~ ~error-biasgsi35 g~]

Substituting the values from above to find the positive TLE, TLE,; = [(l.X511.96)

8.446%] + 1.808%

TI;E~,"= +6.764% span Substituting the values from above to find the negative TLE, TLE," = [(1.15/1.96) " -8.446%] - 0.044%

TLE3; = -5.000% span Converting to process units, TLE~,' = (+6.764% span) '" 1400psi/100%)

TLE~,' = 4-94.70 psi TLE3,- = (-5,000% span) * (1400psi/100%)

TI,&, = -70.00 psi Therefore, TLE3, = 4-94.70 psi, -70.00 psi

Calculation PBNP-IC-39 Revision 4 Page 94 of 117 The cl~oiceof whether to use the positive or negative TLE is dependent upon the process being considered for EOP. Therefore, discretion should be exercised in the S t e m Line Pressure BOP Setpoint calculation WEP-SPT-20.

8.3.5 Total Indicator Loop Error for Parametric (TLE3,)

Using Equation 7.1.2.3-3,

[sa2 + m a 2 + 1a2 + s d 2 + I/1d2 + 1d2 + srn2 + V I ~ '

=I

+ 1m2 + s v 2 + y1v2 + 1v2 sp2+ I / I +~ ~ 4 2

+ Bias

+ 1at2 + 1t2 + shn2+ m12+ a2+ sh2+ m2+ h2 TLE3p + s s 2 + m2+ 1s2 + Sspe, 2 + Sopel,2 Converting to process units, TLE3, = (52.813% span) * (1400 psi)l100%

TL&, = -t 39.39 psi (95195)

Convert to 75/75 error:

= (1.1 5/ 1 -96) * (Section 3.3.3.13 of Ref. G.1)

TLE3, = (1 .1511.96) " It2.813% span = It1.651 % span TILEsp= 21.651% span (75175)

Converting to process ~ulits, TLE3, = (+I .651% span) * (1400 psi)/100%

TILE3, = + 23.11 psi (75175)

Calculation PBNP-IC-39 Revision 4 Page 95 of 117 8.4 Acceptable As-Found and As-Left Calibration Tolerances 8.4.1 Acceptable As-Left Calibration Tolerances 8.4.1.1 Sensor As-Left Tolerances (SAL)

SAL=kSv Section 7.1.4.1 SAL = f 0.500% span Section 8.1.4 Converting from % span to mAdc and rounding to procedure precision:

+

SAL = 0.500% span * (40 nlAdc / 100 % span)

SAL = rt: 0.20 mAdc 8.4.1.2 Current-to-Current Converter As-Left Tolerances (UIAL)

+

VIAL = YIv Section 7.1.4.2 I / W = f 0.500 % span Section 8.1.15 Converting from % span to nAdc and rounding to procedure precision:

+

VIAL = 0.500% span * (40.00 rnAdc / 100 % span)

+

WIAL = 0.20 mAdc 8.4.1.3 Lead/Lag Module As-Left Tolerances (LLAL)

LLAt = LLv+ Section 7.1.4.3 LLAL = f 0.500 % span Section 8.1.24 Converting from% span to Vdc and rounding to procedure precision:

LLAL = 1- 0.500% span * (0.40 Vdc / 100 % span)

LLAL = -t- 0.002 Vdc 8.4.1.4 Indicator As-Left Tolerances (IAL)

I& = st: Iv Section 7.1.4.4 IAL = st: 2.000 % span Section 8.1.52 Converting from % span to Vdc and rounding to procedure precision:

IAL = st: 2.000 % span * (40.00 mAdc / 100 % span)

+

IAL = 0.80 niAdc

Calculation PBNP-XC-39 Revision 4 Page 96 of 117 8.4.1.5 PPCS As-Left Tolerances (PPCSAL)

+

PPCSAL = PPCSv Section 7.1.4.5 PPCSAL = f 0.500 % span Section 5.1.42 Converting from % span to psi and rounding to proceduse precision:

PPCSAL = 10.500 % span * (1400 psi / 100 % span)

PPCSAL = 5 7.00 psi 8.4.1.6 Bistable As-Left Tolerances (BAIL)

BAL-5Bv Section 7.1.4.6 BAL = rfr: 0.500% span Section 8.1.33 Converting to Vdc and rounding to procedure precision (BAL is in Vdc due to the 10Q loop series test point resistor):

BAL = 5 0.500% span (0.40 Vdc / 100 % span)

BAL = ct: 0.0020 Vdc Converting to process units, BAL = (50.500% span) * (1400 psi) / 100%

BAL = 5 7.0 psi 8.4.2 Acceptable As-Found Calibration Tolerances 8.4.2.1 Sensor As-Found Tolerance (SAF)

Using Equation 7.1.3.1, SAF = rfr: Jsv2 -I-s d 2 i s m 2 where:

+

Sv = 0.500 % span Section 8.1.4 Sd =50.518%span Section 8.1.2 Sn1 = ct 0.000 % span Section 8.1.3

CalcuIation PBNP-IC-39 Revision 4 Page 97 of 117 SAF = Its 0.720 % span Converting to 1n.A and rounding to procedure precision:

SAF = + 0.720 % span * (40.00 mAdc / 100 %)

SAF = + 0.29 mAdc 8.4.2.2 Current-to-Current Converter As-Found Tolerance (UIAF)

Using Equation 7.1.3.2, VIAF=+ dI/Iv2 +I/Id2 +I/Im2 where:

YIv = -4 0,500 % span Section 8.1 .I5 VId = 4 0.500 % span Section 8.1.13 VIm +

= 0.095 % span Section 8.1..14 Converting to 1n.A and rounding to procedure precision:

YIAF = rt 0.713 % span * (40.00 mAdc / 100 %)

X/ILAF = Ifi 0.29 mAdc 8.4.2.3 LeadJLag Module As-Found Tolerance (LLAF)

Using Equation 7.1.3.3, LLAF = f JLLV' +L L +~L L~ ~ '

where:

LLv = + 0.500 % span Section 8.1.24 LLd = + 0.500 % span Section 8.1.22 LLm = t- 0.083 % span Section 8.1.23 LLAF = + 0.712 % span Converting to Vdc and rounding to procedui-e precision:

LLAF = 4 0,7120 % span " (0.40 Vdc / 100 %)

Calculation PBNP-IC-39 Revisio114 Page 98 of 117 LLAF = zt 0.0028 Vdc 8.4.2.4 Indicator As-Fotmd Tolerance (IAF')

Using Equation 7.I .3.4, IAF = i--/,,

where:

Iv +

= 2.000 % span Section 5.1.52 Id = -t 1,028 % span Section 8.1.50 Im = f 0.000 % span Section 8.1.51 IAF = f2.249 % span Converting to Vdc and rounding to procedure precision:

LAF = 3- 2.249 % span * (40.00 inAdc / 100 %)

XAF = f0.90 mAdc 8.4.2.5 PPCS As-Found Tolerance (PPCSAF)

Using Equation 7.1.3.5, PPCSAF = i ~ P P C S V + P~ P C S ~ '+ P P C S ~ '

where:

PPCSv = f 0.500 % span Section 8.1.42 PPCSd = f 0.000 % span Section 8.1.40 PPCSm = J. 0.075 % span Section 8.1.41 PPCSAF = f {0.5002 + 0.000~i0.075' +O PPCSAF = f 0.506 % span Converting to psi and rounding to procedure precision:

PPCSAF = f: 0.506 % span * (1400 psi / 100 %)

PPCSAF = 1- 7.1 psi

Calculation PBNP-IC-39 Revision 4 Page 99 of 117 8.4.2.6 Bistable As-Pound Tolerance (BAF)

Using Equation 7.1.3.6, where:

+

Bv = 0.500 % span Section 8.1.33 Bd =kO.212%span Section 8.1.31 Bm = f 0.000 % span Section 8.1.32 BAF = f d0.500~ + 0.212~+ 0.000' +O BAF +

= 0,543 % span Converting to Vdc and rounding to procedure precision:

BAF = + 0.543 % span * (0.4000 Vdc / 100 %)

BAF = f 0.0022 Vdc Converting to processunits, BAF = (*0.543% span) (1400 psi) / 100%

BAF = f 7.6 psi 8.5 Channel Check Tolerance From Section 7.3, the Channel Check Tolerance (CCT) is calculated for two indication loops using the SRSS combination of the allowances (accuracy, drift, setting tolerances, and the readability effect for the sensor, the VI converter and the indicator) for each of the Indicators.

Using Equation 7.3-1 :

Substituting from Section 8.2,

Calculation PBNP-IC-39 Revision 4 Page 100 of 117 0.00~+ 0.500~+ 0.00~+ 0.500~+ 0.500~+ 2.000% 0.5 1g2 + 0.500~

CCT = + 1.028~+ 0 . 0 0 ~+ 0 . 0 0 ~+ 0,500~+ 0 . 0 0 ~c 0.500~1- 0.500~

+ 2.000~+ 0.5182 + 0.500~+ 1.028~+ 0.OO2 CCT = rt-3.557% span (95/95)

Converting from % span to process units and rounding to procedure precision:

CCT = C 3.557 % span * (1400 psi / 100 % span)

CCT = _+ 49.798 psi (95/95)

Per Reference G.26, the Colltrol Room Indication for Low Steam Line Pressure (l(2)PT-468,1(2)PT-469,1(2)PT-482,1(2)PT-478,1(2)PT-479, and 1(2)PT-483) has minor divisions, with each representing 20 psig. Per Section 7.3, the CCT value should be rounded up to the precision that is readable on the associated loop indicator. Per Section

+

3.3.5.3 of Reference G. 1, the readability of these indicators is % the sn~allestdivision (or 10 psig). Therefore, the CCT value is rounded to the nearest 10 psig interval.

CCT = rt: 50.00 psi (95195) 8.6 Low Steam Line Pressure Safety Ix~jectionSetpoints According to Section 7.4, for decreasing setpoints:

Where:

AT, = 320.3 psig (Existing) 395.3 psig (EPU)(Section 6.7)

TLEla-rdll: +

= 8.097 % span (Section 8.3.1)

TLEla-bias'l' +

= 1.808% span (Section 8.3.1)

PS = 1400 psi Conlbine TLE to be used in the equation for single sided setpoints:

Converting to process units,

Calculatio~lPBNP-IC-39 Revision 4 Page 101 of 117 TLE1, = 120.41 psi Substituting this value LTSP = 320.3 (Existing) 395.3; psig (EPU) + 120.41 psi LTSP = 440.71psig (Existing); 515.71 psig (EPU)

From Section 6.7, the actual Field Trip Setpoint (FTSP) for Low Steam Line Pressure Safety Injection is 530 psig. The FTSP is conservative for a decreasing setpoint compared to the calculated LTSP. Per Section 2.0, this setpoint is acceptable, and may be retained.

In addition, per Section 6.7.4, the FTSP of 530 psig is not lower than the b a c h p trip process limit of 500 psig and, therefore, may be retained.

The margin between LTSP and FTSP is calculated in accordance with Section 3.3.8.5 of Reference G. 1 :

Margin = FTSP - LTSP Where:

LTSP = 440.71 psig (Existing); 5 15.71 psig (EPU)

FTSP = 530 psig (Section 6.7)

Substitriting, Margin = 530 psig - 440.71 psig (Existing); 5 15.71 psig (EPU)

Margin= 89.29 psi (Existing) 14.29 psi (EPU) 8.7.1 Lotv Steam Line Pressure Safety Injection Trip Operability Linlit Using Equation 7.1.6-3 to determine the bistable 3 c ~drift value, Rd3, = (1.5) Rd2, (Eq. 7.1.6-3)

Rd3, = (1.5) 0.212 % span (Rd;?,from Section 8.1.3 1)

Rd3, = 0.318 % span The FTSP for the Low Steam Line Pressure Safety Injection Trip of 530 psig (Section 6.7), expressed as percent span, is:

FTSP = ([530 - O] -+ 1400)

100 = 37.86 % span Using Equation 7.1.6-1, the OL~'is determined as:

OL* = FTSP + [RAL2 + ~d-,:]" (Eq. 7.1.6-1)

OL" = 37.86 % + (0.500' + 0,318~f' (RAL is B, from Section 8.1.33)

OL" = 37.86 % + 0.59 OL* = 38.45 % span

Calculation PBm-IC-39 Revision 4 Page 102 of 117 Expressed in psig, oLb= (0.3845

1400) t- 0 = 538.3 psig; Rounded down to 538 psig for calibration.

Using Equation 7.1-6-2, the OL- is determined as:

OL- = FTSP - [RAL~+ ~d~:]" (Eq. 7.1.6-2)

OL- = 37.86 % - (0.500~-I- 0.318~$'

OL- = 37.86 % - 0.59 OL- = 37.27 %span Expressed in psig, OK = (0.3727

1400) + 0 = 521.8 psig; Rounded up to 522 psig for calibration.

Because the Low Steam Line Pressure Safety Injection Trip is a decreasing trip, the negative OL- value of 522 psig should be the li~nitco~nparedto the COT as-found value to determine Technical Specification operability of the chamel. However, an as-found value found outside either the OL' or OL- indicates that the channel is operating abnormally.

From Section 8.6, the most restrictive Limiting Trip Setpoint for the t o w Steam Line Pressure Safety Injection Trip is 5 15.71 psig for EPU. For this decreasing trip, the OK value of 522 psig is more conservative (i.e., restrictive) than the LTSP.

Per Section 2.4, the OC value is acceptable to use for channel operability determination during COT.

8.7.2 Scaling (Existing & EPU) for Low Steam Line Pressure Safety Injection Trip FTSP and Operability Limits Solving for the equivalent signal in mAdc coxresponding to the Existing & EPU FTSP of 530 psig (Section 6.7) using Equation 7.1.7-3, where:

x = 530psig XI = 0 psig y = FTSP (in Vdc) y, ~ 0 . Vdc1 Substituting, Y = l(0.4 Vdc/ 1400 psi) * (530 psig- 0 psig)] 3.0.1 Vdc Y = 0.2514 Vdc For an OL' of 538 psig (Section 8.7.1), t l e equivalent equation is:

Y = [(O.4Vdc/ 1400 psi) * (538 psig - 0 psig)] + 0.1 Vdc Y = 0.2537 Vdc

Calculation PBNP-IC-39 Revision 4 Page 103 of 117 For an OL- of 522 psig (Section 8.7.1), the equivalent equation is:

Y = C(0.4 Vdc/1400 psi) * (522 psig - 0 psig)] 4- 0.1 Vdc Y = 0.2491 Vdc For an AF' of 537.6 psig (Section 8.7), the equivalent equation is:

Y = k(0.4 Vdc/ 1400 psi) * (537.6 psig - 0 psig)] t- 0.1 Vdc Y = 0,2536 Vdc For an AF' of 522.4 psig (Section 8.6), the equivalent equation is:

Y = e(0.4 Vdcf I400 psi) * (522.4 psig - 0 psig)] -t 0.1 Vdc Y = 0.2493 Vdc For an At' of 537.0 psig (Section 5.7), the equivalent equation is:

Y = r(0.4 Vdcl1400 psi) * (537.0 psig - 0 psig)] + 0.1. Vdc Y = 0.2534 Vdc For an M-of 523.0 psig (Section 8.6), the equivalent equation is:

Y = C(0.4 Vdc/ 1400 psi) " (523 psig - 0 psig)] +- 0.1 Vdc Y = 0.2494 Vde For a T.S. AV of 500.0 psig (Section 8.7), the equivalent equation is:

Y = E(0.4 Vdcl 1400 psi) * (500.0 psig - 0 psig)] t- 0.1 Vdc Y = 0.2429 Vdc For a T.S. AV of 520.0 psig (Section 8.7), the equivalent equation is:

Y = C(0.4 Vdc11400 psi) * (520.0 psig - 0 psig)] + 0.1 Vdc Y = 0.2486 Vdc

Calculation PBlW-IC-39 Revision 4 Page 104 of 117 Table 8.7-1 l(2) PC-468,469,478,482,483 - Low Steam Line Pressure Safety Injection Bistable Calibration

Calculation PBNP-IC-39 Revision 4 Page 105 of 117 8.8 Parametric Value Evaluation According to Section 7.1.5, Parametric Values = Tech Spec Linlits + TLE The Technical Require~nentsManual (TRM) establis'tlesa limit on the steani generator pressure. The limit per TSR 3.7.3.1 of Ref. G.58 is steam generator pressure < 200 psig when the Steam Generator vessel shell temperature is < 70 O F . Per the daily logsheets (Ref.

G.56 and G.57), this steam generator pressure limit is only checked when the plant is in modes 4 - 6. However, in any of these modes, there is little to no steam flow, resulting in a negIigible pressure drop from the steam generator to the steam line pressure transmitters.

Therefore, altl~oughthe measurement of interest is Steam Generator Pressure, the steam line pressure measurement is an accurate representation of the pressure in the stesun generator in these modes.

Xn this case, Steam Line Pressure is an increasing process, so the negative TLE is used to determine the parametric value per Section 2.0. From Section 7.1.5, Steam Line pressure limit = I (200 psig + TLE3p)

TLE3, = - 23.1 1 psi (Section 8.3.5)

Substituting into the above equation:

Steam Line pressure limit = < (200 psig -I--23.11)

Steaxn Line pressure litnit = < 176.89 psig Per Ref G,26, the smallest division on the indicators is 20 psig. Per Section 3.3.5.3 of

+

Reference G.1, the readability of these indicators is %. the snlallest division (or 10 psig).

Therefore, the parametric value is rounded down to the nearest 10 psig interval.

Steam Line pressure limit = I170 psig This parametric value of 170 psig ensures conlpliance with TSR 3.7.3.1 (Ref G.58) by having the operator verify the steam generator vessel shell temperature is >70 O F if steam line pressure is >I69 psig.

Therefore, although 169 psig cannot be read on the indicators, the >I 69 psig value from the logsheets is still acceptable because 170 psig can be read, and if the ilidicator reads 170 psig or above, the log sheet dictates that the steam generator vessel shell temperature must be verified to be >70 OF. Therefore, both the parametric value and log sheet linrits are acceptable to ensure compliance with TSR 3.7.3.1 (Ref G.58).

Calculation PBNP-IC-39 Revision 4 Page 106 of 117 9.0 RESULTS AND CONCLUSIONS 9.1 Total Loop Error Total Loop Errors calculated in Section 8.3 are shown below:

9.2 Acceptable As-Left and As-Found Tolerances This Calculation has determined the Acceptable As-Found and As-Left Tolerances for the instruments listed in Section 1.5. The values are rounded to the precision of the Calibration Procedures. The new As-Found and As-Left Tolerances should be incorporated into the affected Calibration Procedures identified in Section 10.0.

CaIculation PBNP-TC-39 Revision 4 Page 107 of 117 n en ..- A J- j Section I 9.3 Limiting Trip Setpoixlts, Operability Limits (OL), and Reconirne~xdedTech Spec Changes hR 896611 deteimined that the Technical Specification Allowable Values for several protection system functions in TS 3.3.1 (RPS) and TS 3.3.2 (ESFAS) were uon-conservative.

As a result, the 1&C calibration procedures were revised to illstall temporary admix~istrative limits (termed Allowable Linlits in the ICPs) on the trip bistable as-found values until a license amendment is approved to revise the TS sections.

The Limiting Trip Setpoints for primary trip functions deteimined in this calculation provide new Technical Specification limits (Allowable Values) for channel operability to protect the accident analyses Analytical Limits. The LTSPs also satisfy the definition of a Limiting Safety System Setting in 10CFR50.36. Backup trips and permissives do not have a LTSP that can be used as an Allowable Value in Tech Specs because there is no analytical limit to "anchor" the LTSP. Therefore, it is reconmended that the LTSPs for the primary tiip filnctions be incIuded in a license ainendment to revise RPS TS 3.3.1, Table 3.3.1-1 and ESFAS TS 3.3.2, Table 3.3.2-1 Allowable Values.

Operability Limits have been determined for all trip h c t i o n s (primary trips, backup trips, and the SI Block/UnbIock fiu~ction).The OLs provide new limits to be applied in the I&C

Calculation PBNP-IC-39 Revision 4 Page 108 of 117 calibration procedures for establishing Technical Specification operability of the trip channels during Channel Operational Testing (COT).

It is recon~mendedthat the Operability Limits for both primary and backup trips be included in the Technical Requirements Manual (TRM) as limits (more restrictive than the LTSPs) for establishing channel operability during channel surveillance testing. The reason for including OLs in the 3X.M rather than the Technical Specificatioils is to allow the station flexibility to revise the field setpoint values, along with their as-left, as-fokd, and OL values, without requiring prior NRC approval. The LTSPs, which provide protection for the accident analyses, are the appropriate Allowable Values for the protection f!unctions in the Specifications and wouId remain bounding limits for the primary trips (only).

It is also recommended that a license amendment be submitted to revise the Low Steam Line Pressure Safety Injection Trip Allowable Value (currently 2500 psig in TS Table 3.3.2-1) with a new Allowable Value of 2520 based on conservatively selecting a value above the LTSP of 5 16 psig for this decreasing setpoint.

The following Operability Limits are proposed to be added to the bistable calibration procedures, as shown in the procedure markups in Attachment A.

Table 9.21 Operability Limits for Existing and EPU Conditions

Calculation PBNF'-1C-39 Revision 4 Page 109 of 117 Channel Check Tolerance This calculation detennined the Channel Check Tolerance for the Steam Line Pressure Indicators. The existing CCT is less than the calculated CCT and therefore may be retained.

Table 9.3-1, Channel Cheek Tolerances 9.4 Setpoint Evaluations Per Section 5.6 and 2.0, the Existing and EPU LTSP's and FTSP's with associated Margins are provided in Table 9.4-1 (Below).

Table 9.4-1, Setpoints 9.5 Technical Specification Allowable Values Per Section 8.7 and 2.0, the following Technical Specification Allowable Values (AV) 11ave been determined for Existing and EPU operations.

Table 9.5-1, Calculated Allowable Valaes

Calculation PBNP-1C-39 Revision 4 Page 110 of 117 9.6 Parametric Value Evaluation Per Section 8.8 and 2.0, the existingParametric value is acceptable. Therefore, no changes are required.

Table 9.6-1, Calculated Parnmetric Value Existing Parametric Calculated Parametric Reference VaIue Value 5170 psig 176.89 psig Section 8.8

Calculation PBNP-IC-39 Revision 4 Page 111 of 117 9.7 Limitations 9.7.1 M&TE Limitations To preserve the validity of this calculation's results, this calculation requires that all hture calibrations of the equipment (addressed in this calculation) be performed using the M&TE equivalent to that mentioned below (or better).

Table 9.6-1, Limitatioiis 9.7.2 Ten~peratureLimitations The results of this calculation are valid only if the temperature inside the ControVComputer Room instrumentation panels does not exceed 120 OF (For EOP inputs and trips). GAR 0103 1656 has been generated to track this limitation.

9.7.3 Implementatior~Limitation Changes recommended by this calculation, such as As-Foulid and As-Left Tolerances are NOT to be implemented without approval of the PBNP Design Authority or the appointed designee.

CalcuIation PBNP-IC-39 Revision 4 Page 112 of 117 9.8 Graphical Representation of Setpoints 538.0 psig (0.2537 Vdc) 537.6 psig (0.2536 Vdc) 537.0 psig (0.2534 Vdc)

FTSP 530.0 psig (0.2514 Vdc)

-As-Left (-AL) 523.0 psig (0.2494 Vdc)

-As-Found (-AJ?) 522.4 psig (0.2492 Vdc)

-Operability Limit (-OL) 522.0 psig (0.249 1 Vdc)

Existing Allowable Value (AV) SO0 psig LTSP 440.71 psig Calculated Allowable Value (AV) 428.66 psig Analytical Limit (AL) 320.3 psig Figure 9,S.X-1, Low Steam Line Pressure Safety I~ijectionSetpoirlt (Existing)

Calculation PBNP-IC-39 Revision 4 Page 113 of 117

+Operability Limit (4-OL) 538 psig (0.2537 Vdc)

I-As-Found (+AF) 537.6 psig (0,2536 Vdc)

+As-Left (+AL) 537.0 psig (0.2534 Vdc)

FTSP 530.0 psig (0.2514 Vdc)

-As-Left (-AL) 523.0 psig (0.2494 Vdc)

-As-Foulld (-A??) 522.4 psig (0.2492 Vdc)

-Operability Limit (-OL) 522 psig (0.2491 Vdc)

EPU Allowable Value (AV)

LTSP Analytical Limit (AL)

Figure 9.8.2-2, Low Steam Line Pressure Safety Illjectiolx Setpoint (EPU)

Calculation PBNP-IC-39 Revision 4 Page 114 of 117 10.0 IMPACT OM PLANT DOCUMENTS Note 1:Passport Engineering Change (EC) Number for Calculatio~lPBNP-IC-39 Rev. 4 is 13207 10.1 IICP 04.001E, "Reactor Protection and Safeguards Analog Racks Steam Pressure Refueling Calibration," Rev. 8 Add new Operability Litnits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.2 21CP 04.001E, "Reactor Protection and Safeguards Analog Racks Steam Pressure Refueling Calibration," Rev. 8 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.3 IICP 02.001RD, "Reactor Protection and Engineered Safety Features Red Channel Analog 92 Day Surveillance Test", Rev. 11 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.4 lXCP 02.001BL, "Reactor Protection and Engineered Safety Features Blue Channel Analog 92 Day Surveillance Test", Rev. 13 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.5 IICP 02.001WH, "Reactor Protection and Engineered Safety Features White Channel Analog 92 Day SurveillanceTest", Rev. 12 Add new Operability Limits for tile Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.6 I ICP 02.00 1YL, "Reactor Protection and Engineered Safety Features Yellow Channel Analog 92 Day Surveillance Test", Rev. 11 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.7 21CP 02.001RD7"Reactor Protection and Engineered Safety Features Red Channel Analog 92 Day Surveillance Test", Rev. 11 Add new Operability Limits for the Low Steain Line Pressure Safety Injection Safety Analysis Setpoint.

Calculation PBNP-IC-39 Revision 4 Page 115 of117 21CP 02.001BL, "Reactor Protection and Engineered Safety Features Blue ChanneI Analog 92 Day Sxu-veillanceTest", Rev. 14 Add new Operability Linlits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

21CP 02.001Wl3, "Reactor Protection and Engineered Safety Features White Channel Analog 92 Day Surveillance Test", Rev. 11 Add new Operability Linlits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

IICP 02.020RD, "Post-Refueling Pre-Startup RPS and ESP Red Chasmel Analog Surveillance Test", Rev. I I Add new Operability Limits for the Low Stearn Line Pressure Safety Injection Safety h a l y s i s Setpoint.

2ICP 02.020RCt, "F'ost-Refueling Pre-Startup RPS and ESF Red Channel Analog SurveillanceTest", Rev. 10 Add new Operability Limits for the Low Steam Line Pressure Safety Injectio~lSafety Analysis Setpoint.

IICP 02.020BL, "Post-Refileling Pre-Startup RPS and ESF Red Channel Analog Surveillance Test7',Rev. 10 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

21CP 02.020BL' "Post-Refueling Pre-Startup RPS and ESF Red Channel Analog SurveillanceTest", Rev. 10 Add new Operability Limits for the Low Steam Line Pressure Safety lnjeclion Safety Analysis Setpoint.

IXC-P 02.020WJ3, "Post-Refueling Pre-Startup RF'S and ESF Red Channel Analog SurveillanceTest", Rev. 10 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

2ICP 02.020WH7"Post-Refueling Pre-Startup RPS and ESF Red Channel Analog SurveillanceTest", Rev. 10 Add new Operability Linlits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

Calculation PBNP-IC-39 Revision 4 Page 116 of 117 10.16 lICP 02.020YL, "Post-Refueling Pre-Startup RPS and ESF Red Channel Analog SurveillanceTest", Rev. 10 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.17 21CP 02.020YL, "Post-Refueling Pre-Startup RPS and ESF Red Channel Analog SurveillanceTest", Rev. 10 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.18 2ICP 02.001YL, "Reactor Protection and Engineered Safety Features Yellow Channel Analog 92 Day Surveillance Test", Rev. 12 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.19 Point Beach Nuclear PIant Technical Specifications, Section 3.3.2, B3.3.2, Amendment 201(Ul) and Amendment 206 (U2), Rev. 0 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

10.20 PBNP Setpoint Document STPT 2.1, "Safety Injection", Rev. 2 Add new Operability Limits for the Low Steam Line Pressure Safety Injection Safety Analysis Setpoint.

Calculation PBNP-IC-39 Revision 4 Page 117 of 117 11.0 ATTACHMENT LIST 11.1 Attachment A - Instrument Scaling for Calibration Procedure l(2)ICP 04.004-2, l(2)ICP 04.001E, 1(2) 02.002RD, l(2) 02.002BL, l(2) 02.002W, 1(2) 02.002YL, 1(2) 02.020RD, l(2) 02.020BL, l(2) 02.020WH, and l(2) 02.02012 (21 pages) 1 1.2 Attachment B - Walkdown Calculation No. PBNP-IC-39, dated 6/12/06 (2pages) 11.3 Attachment C - Walkdown Calculation No. PBNP-IC-39, dated 7/17/06 (2 pages)

Attachment A Calculation No. PBNP-IC-39 Revision 4 Paee A l of A21 This calculation has determined Acceptable As-Found Tolerances for all instruments identified in Section 1.5. The following tables illustrate the necessary modifications to calibration procedures P.1 through. P.3, P.5 tlxough P.9, and P. 11 through P. 14 to account for these new tolerance values per Rev. 2 of this calculation. The area within the bolded box represent the necessary changes, all other fields are provided for convenience only.

Attachment A CalculationNo. PBNP-IC-39 Revision 4 Page A2 of A2 1

Attachment A Calculation No. PBNP-IC-39 Revision 4 Paee A3 of A21

Attachment A Calculation No. PBNP-IC-39 Revision 4 P a ~ A4 e of A21

Attachment A Calculation No. PBNP-IC-39 Revision 4 Pane A5 of A21

Attachment A Calculatioll No. PBNP-IC-39 Revision 4 Pane A6 of A2 1

Attachment A Calculatiorl No. PBNP-IC-39 Revision 4 Pane A7 of A21

Attachment A Calculatio~lNo. PBNP-IC-39 Revisioil4 Page A8 of A21

Attachment A Calculatio~lNo. PBNP-IC-39 Revision 4 Page A9 of A21

Attachment A Calculation No. PBNP-IC-39 Revision 4 Page A10 of A21 As-Left Tolerance

Attachment A Calculation No. PBNP-IC-39 Revision 4 Page A1 I of A21

Attachment A CalculationNo. PBNP-IC-39 Revision 4 Pane A12 of A21 1(2)ICP 02.0013RD (Existing)

Attachment A Calculation No. PBNP-IC-39 Revision 4 Page A1 3 of A2 1 1(2)ICP 02.001BL (Existing)

Attachment A CalcuIatio~~

No. PBNP-IC-39 Revision 4 Page A14 of A21 1(2)ICP 02.00 1YL (Existing)

Calculation No. PBW-IC-39 Attachment A Revision 4 Page A15 0f A21

Attachment A Calculation No. PBNP-XC-39 Revision 4 Page A1 6 of A21 l(2)ICP 02.020RD (Existing)

Attachment A Calculation No. PBNP-IC-39 Revision 4 Paee A17 of A21

Calculatiorl No. PBNP-IC-39 Attachment A Revision 4 Page A1 8 of A21

Attachment A CalculatiollNo. PBNP-IC-39 Revisior~4 Page A1 9 of A21

Attachment A Calculation No. PBNP-IC-39 Revision 4 Paee A20 of A21 l(2)ICP 02.020YL (Existing)

Calculation No. PBNP-IC-39 Revision 4 Page A21 of A21 Per Section 9.6, to preserve the validity of this calculation's results, this calculation requires that all fulure calibrations of the equipment (addressed in this calculation) be perfomled using the M&TE mentioned below (or better). This table needs to be implen~entedin calibration procedures l(2)ICP 04.004-2, 1(2)ICP 04.001E, l(2)ICP 02.001RD, l(2)ICP 02.001BL, l(2)ICP 02.001WI-I, and l(2)ICP 02.001YL to provide the calibrator with a list of acceptable M&TE equipment.

2 0.000025 Vdc Fluke 8842A 0 - 2.0 Vdc

(& 0.025 % RDG t- 2 DGTS) rt0.030 mAdc IJP 34401A 0 - 100 mAdc (k 0.050 % RDG i- 0.005% RNG) k0.000027 Vdc rt 0.004 % RDG i- 0.0007% RN

Attachment 3 Calculation No. PBNP-IC-39 Revision 4 Paee B 1 of B2 PBNP-IC-39 Descr~beor illustrate the minor divisions associated with the Low Steam Line (Steam Generator)

Pressure Indicators: 1(2)Pl-468,1(2)Pl-469,1(2)PI482A, 1(2)Pl478, 1(2)P1479, and 7 (2)Pi-483A.

Data Tolerance Requirements L I PI-PB-029, ATTACHMENT 3 PAGE Iof 2

Attachment 3 Calculation No. PBNP-IC-39 Revision 4 Page B2 of B2 PART 2 WALKDOWN DATA COLtECTlON FORM Results Pressure indicators 1(2)Pl-468,1(2)Pl-469, 1(2)Pl482A, 1(2)P1478,1(2)P1479, and 1(2)PI483A are identical to one another. Each ~nstrumentis a horizontalgauge with a needle indicator. The indicated process range is 0 - 1400 PSIG uniformly distrtbuted over the scale, with minor divisions of 20 PSIG.

See illustration below for sample.

The divisions appear as follows: I 11111 11111 0 200 Data Taker Name Signature Mer/=5 . S k [

Independent ~errfie;~ame Signature Date PI-PB-029. ATTACHMENT 3 PAGE 2 of 2

Attachment C Calculation No. PBNP-IC-39 Revision 4 Paee C1 of C2 PART. -

I. WALKDOWN REQUEST FORM Calculation No. PBNP-IC-39 Walkdown Location (BfdglElevlRoomlCo1umn Lines)

I 1HX-1A SG PressureTransmitters: 46', Spent Fuel Pool Room, PAB 1HX-1B SG Pressure Transmitters: 66',Fan Room, PAB Scope Deterrntne the distance of floor elevation (46') to 2HX-1A SG Pressure Transmitters (1(2)PT-468, 1(2)PT-469, and 1(2)PT-482).

Determine the d~stanceof floor elevat~on(66') to IHX-1B SG Pressure Transm~tters(l(2)PT-478, 1(2)PT-479, and l(2)PT-483).

References:

Data Tolerance Requirements W. Barasa SignatUte ate 7-28 -a&

Lead PI-PB-029. ATTACHMENT 3 PAGE 1 of -

Attachment C CalcuIation No. PBNP-IC-39 Revision 4 Paee C2 of C2

[06~15-f L. M M S N Data Taker Name Independent Verifier Name Signature Date PAGE 2 of -

v t e Letter Sequence Response to RAI
TAC:ME1044, Clarify Application of Setpoint Methodology for LSSS Functions (Approved, Closed)
Initiation Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request Acceptance... Supplement, Supplement, Supplement, Supplement Administration Meeting Questions 2 August 2010 11 August 2010 8 November 2010 4 October 2010 Answers 13 May 2010 25 September 2009 21 November 2009 21 November 2009 16 December 2009 30 November 2009 21 December 2009 29 April 2010 30 April 2010 11 June 2010 23 August 2010 26 August 2010 27 September 2010 13 January 2011 Results Approval Other: ML102810591
MONTHYEAR2010-04-29 [Table View]

NRC 2010-0060, License Amendment Request 261 Extended Power Uprate, Response to Request for Additional Information

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NRC 2010-0060, License Amendment Request 261 Extended Power Uprate, Response to Request for Additional Information

Text

References:

Enclosures:

1.0 BACKGROUND

1.1 Background

4.0 REFERENCES

Reference:

1.0 BACKGROUND

4.0 REFERENCES

1.0 BACKGROUND

1.1 Background

References:

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