ML093070164

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Technical Report No. EE-0116, Revision 5
ML093070164
Person / Time
Site: Kewaunee, Surry, North Anna  Dominion icon.png
Issue date: 10/15/2009
From: Mcgrath D
Dominion Energy Kewaunee
To:
Office of Nuclear Reactor Regulation
References
09-491A, NDCM-3.11, TAC ME02467 EE-0116, Rev 5
Download: ML093070164 (206)
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Text

No. 16, REVISION 5 ANNA IMPROVED TECHNICAL (ITS) 3.3.1~1 AND 3.3.2~1, LIMITS FOR SURRY CUSTOM TECHNICAL SPECIFICATIONS (CTS), SECTIONS 2.3 AND 3.7, AND ALLOWABLE VALUES FOR KEWAUNEE POWER STATION IMPROVED SPECIFICATIONS (ITS) FUNCTIONS LISTED IN SPECIFICATION 5.5.16 NORTH ANNA POWER STATION, SURRY POWER STATION, AND MUI'II1l;;;.1I.;;; POWER STATION ELECTRICAUI&C/COMPUTERS DOMINION l'IIUlvll..B;;;Mri ENIGINIEEIRINIG LIIILUL..1nI 2009 Prepared By: Date Prepared By: Date Reviewed By: Date Concurrence By: Date Approved By: Date Key Words: Allowable Values As Found Tolerances ESFAS Instrumentation Improved Technical Specifications Limiting Safety System Settings Reactor Protection System Instrumentation Setting Limits Setpoints (June 2006)

EE-0116 Revision 5 Record of Revision Rev 0 Original Issue.

Rev 1 1 Changed the calculation of the Allowable Values for North Annas High Steam Flow in 2/3 Steam Lines ESFAS initiation on Page 23. The revised Allowable Values are based on using only 1 Rack Drift (RD) term for the function. This change yields more conservative Allowable Values.

2. Changed the calculation of the Allowable Values for Surrys High Steam Flow in 2/3 Steam Lines ESFAS initiation on Pages 29 and 30. The revised Allowable Values are based on using only 1 Rack Drift (RD) term for the function. This change yields more conservative Allowable Values.
3. Changed the Allowable Values and verbiage on Page 42 for the North Anna High Steam Flow in 2/3 Steam Lines ESFAS initiation.
4. Deleted the Allowable Values for the enable manual block of Safety Injection for North Anna Permissives P-11 and P-12 and revised the verbiage accordingly on Page 47.
5. Changed the Allowable Values and verbiage on Page 56 for the Surry High Steam Flow in 2/3 Steam Lines ESFAS initiation.
6. Deleted the Allowable Values for the enable manual block of Safety Injection for Surry Permissives P-11 and P-12 and revised the verbiage accordingly on Page 63.

Rev 2 1. Page 16 - Changed Rack Drift term RD4 from 1.0 % span to 0.0 % span in Figure 3.2-5 to obtain a more conservative Allowable Value for the OTT Reactor Trip Setpoint.

2. Page 18 - Changed Rack Drift term RD4 from 1.0 % span to 0.0 % span to be consistent with Calculation EE-0415. This change yields a more conservative Allowable Value for the OTT Reactor Trip Setpoint.
3. Page 24 - Changed Rack Drift term RD4 from 1.0 % span to 0.0 % span in Figure 3.3-2 to obtain a more conservative Allowable Value for the OTT Reactor Trip Setpoint.
4. Page 25 - Changed Rack Drift term RD4 from 1.0 % span to 0.0 % span to be consistent with Calculation EE-0434. This change yields a more conservative Allowable Value for the OTT Reactor Trip Setpoint.
5. Pages 25 and 26 - Revised calculations shown in Methods 1a through 2b based on Rack Drift Term RD4 = 0.0 % span.
6. Page 31 - Changed Rack Drift term RD4 from 1.0 % span to 0.0 % span in Figure 3.3-4 to obtain a more conservative Allowable Value for the OPT Reactor Trip Setpoint.
7. Page 32 - Changed Rack Drift term RD4 from 1.0 % span to 0.0 % span to be consistent with Calculation EE-0415. This change yields a more conservative Allowable Value for the OPT Reactor Trip Setpoint. The Allowable Value calculation shown on Page 32 was revised based on RD3 = 0.0 % span.

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EE-0116 Revision 5

8. Pages 34 and 35 - Revised NAPS OTT Reactor Trip Allowable Value and associated verbiage in Item 4.1.8.
9. Page 47 - Added another Allowable Value for NAPS Permissive P-12 and revised associated verbiage in Item 4.2.38.
10. Page 49 - Revised SPS OTT Reactor Trip Allowable Value and associated verbiage in Item 4.3.6.
11. Page 49 - Revised verbiage associated with the SPS OPT Reactor Trip Allowable Value in Item 4.3.7.
12. Page 63 - Added another Allowable Value for SPS Permissive P-12 and revised associated verbiage in Item 4.4.42.

Rev 3 Revision 3 to this Technical Report is a major revision. The Allowable Values for North Annas ITS and the Setting Limits for Surrys CTS are derived and based on Methods 1 or 2 as described in Part II of ISA-RP67.04.02-2000. This revision will require a complete review from cover to cover. This Technical Report will be used as the design basis for Technical Specifications Change Request 318 at Surry Power Station. In addition, this Technical Report will also be used as the design input for a future Technical Specifications Change Request for North Anna to change selected Allowable Values as noted in this report.

In accordance with NDCM 3.11 the Required Actions and Tracking Mechanism will be documented in Engineering Transmittal ET-CEE-06-0020, Rev. 0 Transmittal of CDS and PRC for Technical Report EE-0116, Rev. 3. In addition, the results of Technical Report EE-0116, Rev. 3 will be screened as part of ET-CEE-06-0020, rev. 0 and will not be repeated herein.

Rev 4 1. Page 5 - Added Cot or Non-Cot to the error terms in Table 2.1.

2. Page 9 - Changed the wording under item 3 to reflect that some Allowable Values have been rounded as per discussions with the NRC and Surry TSCR 318.
3. Page 13 - Changed the Rack Error Terms for M1MTE and M5MTE due to the revised CSA calculation EE-0063.
4. Page 33 - Changed the Power Range Neutron Flux High Setpoint Reactor Trip due to the revised CSA calculation EE-0063.
5. Page 34 - Changed Figure 4.1.2 for the Power Range Neutron Flux High Reactor Trip and changed the Power Range Neutron Flux Low Setpoint Reactor Trip due to the revised CSA calculation EE-0063.
6. Page 35 - Changed Figure 4.1.3 for the Power Range Neutron Flux Low Setpoint Reactor Trip due to the revised CSA calculation EE-0063.
7. Page 45 - Changed the Pressurizer High Pressure Reactor Trip due to the Safety Analysis Limit being changed from 2381.3 PSIG to 2391.3 PSIG based on ET-NAF-08-0061.
8. Page 47 - Changed Figure 4.1.10 for the Pressurizer High Pressure Reactor Trip due to the Safety Analysis Limit being changed from 2381.3 PSIG to 2391.3 PSIG based on ET-NAF-08-0061.

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EE-0116 Revision 5

9. Page 48 - Changed the Reactor Coolant Flow Low Reactor trip due to the revised CSA calculation EE-0060.
10. Page 49 - Changed Figure 4.1.12 for Low Reactor Coolant Flow Reactor Trip due to the revision of CSA calculation EE-0060.
11. Page 53 - Changed the Permissive P-8, Power Range Neutron Flux due to the revised CSA calculation EE-0063.
12. Page 54 - Changed Figure 4.1.24 for the Power Range Reactor Trip Permissive P-8 due to the revised CSA calculation EE-0063.
13. Page 57 - Changed Figure 4.2.3 for Containment Pressure HI-1 ESFAS Initiation due to the revised Containment Partial Pressure operating Limits per Technical Report NE-1472, Revision 0.
14. Page 62 - Changed the TAVG Low-Low ESFAS Initiation due to the revised CSA calculation EE-0434.
15. Page 64 - Changed Figure 4.2.7 for TAVG Low Low ESFAS Initiation due to the revised CSA calculation EE-0434.
16. Page 68 - Changed Figure 4.2.11 for Containment Pressure HI-3 ESFAS Initiation due to the revised Containment Partial Pressure operating Limits per Technical Report NE-1472, Revision 0.
17. Page 71 - Changed Figure 4.2.20 for Containment Pressure HI-2 ESFAS Initiation due to the revised Containment Partial Pressure operating Limits per Technical Report NE-1472, Revision 0.
18. Page 75 - Deleted the Analysis for > 19.0 % Wide Range Level and the Analysis for < 20.0 Wide Range Level for the Refueling Water Storage Tank Level - Low Low. With the implementation of DCP 06-013 and 06- 015 these analysis are no longer valid.
19. Page 77 - Deleted Figure 4.2.34a. This Figure is no longer applicable with the implementation of DCP 06-013 and 06-015. Changed Figure number to 4.2.34.
20. Page 78 - Changed the TAVG, P-12 ESFAS Permissive due to the revised CSA calculation EE-0434.
21. Page 79 - Changed Figure 4.2.38 for ESFAS Permissive P-12 due to the revised CSA calculation EE-0434.
22. Page 103 - Incorporated Addendum 1 for the Turbine First Stage Pressure Input to Permissive P-7.
23. Page 106 - Changed the word or to and for Permissive P-10, Power Range Neutron Flux.
24. Page 107 - Changed the Containment Pressure - High, Engineered Safety Features Actuation System (EFAS) Instrumentation Setting Limits due to the revised Safety Analysis Limits in Technical Report NE-0994, Revision 15.

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EE-0116 Revision 5

25. Page 108 - Changed Figure 4.4.2 for the new Safety Analysis Limit from Technical Report EE-0994, Revision 15 and updated operating limits per Technical Report NE-1460, Revision 1.
26. Page 119 - Determined the Voltage and Time corresponding to the new Allowable Value for Low Intake Canal Level.
27. Page 122 - Changed the Refueling Water Storage Tank Level Low - Low RMT Initiation, EFAS Instrumentation Setting Limits due to the revised Safety Analysis Limits in Technical Report NE-0994, Revision 14.
28. Page 124 - Changed Figure 4.4.12 due to the revised Safety Analysis Limit in technical Report NE-0994, Revision 14.
29. Page 128 - Changed References 5.1, 5.2, and 5.15 to reflect the current revision.
30. Page 129 - Changed References 5.18, 5.21, 5.23, 5.26, 5.27, 5.33 to reflect the current revision.
31. Page 130- Changed References 5.35, 5.36, 5.40, 5.41, 5.44 through 5.62 to reflect the current revision.
32. Page 132 - Changed References 5.63 through 5.65 and 5.67 through 5.69 to reflect the current revision. Deleted Reference 5.77.
33. Page 133 - Changed References 5.80 through 5.82 to reflect the current revision. Added Reference 5.88, ET-NAF-08-0061, Rev. 0 Implementation of Revised Safety Analysis Limit for High Pressurizer Pressure Reactor Trip, North Anna Units 1 and 2.

Rev. 5 Revision 5 to this Technical Report is a major revision. Kewaunee Power Stations Setpoint Control Program has been added to the report to support Kewaunees conversion to Improved Technical Specifications (ITS).

1. Page 3 - Added Kewaunees Setpoint Control Program to Section 1.1, Purpose.
2. Page 3 - Added Kewaunee LCOs 3.3.1, 3.3.2, 3.3.5, 3.3.6, and 3.3.7 to Section 1.2, Scope.
3. Page 4 - Added and updated definitions in Section 2.1 to reflect Kewaunees Setpoint Control Program and the adoption of TSTF-493, Rev. 4, Option B.
4. Page 5 - Added and updated definitions in Section 2.1 to reflect Kewaunees Setpoint Control Program and the requirements from TSTF-493, Rev. 4 and RIS 2006-17.
5. Page 9 - Updated Section 2.2.2 to reflect current conditions for North Anna and Surry. Also, a discussion for Kewaunee was added to address the Setpoint Control Program.
6. Page 10 - Added a discussion in Sections 2.2.2 and 2.2.3 pertaining to the issuance of RIS 2006-17.
7. Page 11 - Added a discussion in Section 2.2.4 pertaining to the issuance of TSTF-493, Rev. 4.
8. Pages 12 and 13 - Added Section 2.2.6 to address Kewaunees adoption of TSTF-493, Rev. 4, Option B.

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EE-0116 Revision 5

9. Page 14 - Added Kewaunee to the discussion in Sections 3.1 and 3.2.
10. Page 15 - Updated information to reflect current conditions for North Anna and Surry and to add Kewaunees Setpoint Control Program nomenclature.
11. Page 18 - Updated information to reflect current conditions for Surry.
12. Page 19 - Added discussion for Kewaunees Protection and Control System.
13. Page 20 - Continued discussion of Kewaunees Protection and Control System and updated information to reflect current conditions for North Anna.
14. Pages 21, 22, and 23 - Revised the Multiple Parameter Protection Functions discussion to evaluate Kewaunees OTT instead of Surrys.
15. Page 24 - Added Kewaunee in the Notes section where applicable.
16. Pages 39 Through 45 - Added Section 3.5 to describe Kewaunees Setpoint Methodology.
17. Page 65 - Revised wording of the Allowable Value for North Annas Steam Flow Feed Flow Mismatch Reactor Trip.
18. Pages 74 through 76 - Revised North Annas High Steam Flow ESFAS analysis to reflect the results of Calculation EE-0736, Rev. 5 and to reflect conditions at 20 % power.
19. Page 91 and 92 - Added the analysis for North Annas RWST Low Level ESFAS function based on DCP 59-DCP-06-013 and DCP 59-DCP-06-015.
20. Pages 104 through 107 - Corrected error in Surrys OTT analysis. There is no change to the current LSSS and there is still positive margin to the Safety Analysis Limit for the three conditions analyzed.
21. Page 118 - Corrected error in the description of the operation of P-7 and P-10.
22. Page 129 and 130 - Updated Surrys High Steam Flow ESFAS analysis based on unit specific PREF values and to reflect conditions at 20 % power.
23. Pages 143 through 169 - Added Section 4.5 to perform the setpoint analysis for Kewaunees Reactor Protection System (LCO 3.3.1) to support the Setpoint Control Program.
24. Pages 170 through 185 - Added Section 4.6 to perform the setpoint analysis for Kewaunees Engineered Safety Features Actuation System (LCO 3.3.2) to support the Setpoint Control Program.
25. Pages 186 through 190 - Added Section 4.7 to perform the setpoint analysis for Kewaunees Loss of Offsite Power (LOOP) Diesel Generator (DG) Start Instrumentation (LCO 3.3.5),

Containment Purge and Vent Isolation Instrumentation (LCO 3.3.6), and Control Room Post Accident Recirculation (CRPAR) Actuation Instrumentation (LCO 3.3.7) to support the Setpoint Control Program.

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EE-0116 Revision 5

26. Pages 191 through 199 - Updated references for North Anna and Surry and added references for Kewaunee to support the analyses performed in Sections 4.5 through 4.7.

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EE-0116 Page 1 of 199 Revision 5 TABLE OF CONTENTS SECTION PAGE

1.0 INTRODUCTION

3 1.1 Purpose 3 1.2 Scope 3 2.0 OVERVIEW 4 2.1 Definitions 4 2.2 The Significance of the Allowable Value 8 2.2.1 Background 8 2.2.2 Addressing Recent NRC Concerns Associated With Allowable Values 8 2.2.3 The NRC Staff Position Concerning the LSSS and AV 10 2.2.4 The ISA/ NEI/Various Industry Groups Position Concerning the LSSS and AV 10 2.2.5 The Dominion Position Concerning the LSSS and AV for North Anna and Surry 11 2.2.6 The Dominion Position Concerning the LSSS and AV for Kewaunee 12 3.0 METHODOLOGY 14 3.1 Introduction 14 3.2 Functional Groups for RPS(RTS) and ESFAS Instrumentation 14 3.3 The Instrumentation, Systems and Automation Society (ISA) Methodologies Used to Calculate Allowable Values 24 3.3.1 Method 1 25 3.3.2 Method 2 26 3.3.3 Method 3 26 3.3.4 Method 3 with Additional Margin 27 3.4 Methodology for Determining North Anna Allowable Values and Surry LSSS/Setting Limits 29 3.4.1 Primary RTS and ESFAS Trips and Permissives Credited in the Safety Analysis 29 3.4.2 Backup RTS and ESFAS Trips and Permissives Not Credited in the Safety Analysis 30 3.4.3 Calculating Actual Allowable Values for North Anna and LSSS/Setting Limits for Surry 31 3.5 Methodology for Determining Kewaunees Allowable Value and Limiting Trip 39 Setpoint Based on TSTF-493 and RIS 2006-17 3.5.1 Primary RPS and ESFAS Trips, Permissives, and Other LCOs Credited in the 39 Kewaunee Safety Analysis 3.5.2 Backup RPS and ESFAS Trips, Permissives and Other LCOs Not Credited in the 41 Kewaunee Safety Analysis 3.5.3 Calculating Limiting Trip Setpoints, Allowable Values, and As Found 42 Tolerances for Kewaunee Power Station

EE-0116 Page 2 of 199 Revision 5 TABLE OF CONTENTS (CONTINUED)

SECTION PAGE 4.0 RESULTS 46 4.1 Allowable Values for North Anna ITS Table 3.3.1-1 (RTS Instrumentation) 46 4.2 Allowable Values for North Anna ITS Table 3.3.2-1 (ESFAS Instrumentation) 69 4.3 Limiting Safety System Settings (LSSS) for Surry Power Station Custom Technical 95 Specifications, Section 2.3, Limiting Safety System Settings, Protective Instrumentation and Protective Instrumentation Settings for Reactor Trip Interlocks.

4.4 Setting Limits for Surry Power Station Custom Technical Specifications, Table 3.7-4, 122 Engineered Safety Features Actuation System Instrumentation Setting Limits and Table 3.7-2, Engineered Safety Features Actuation System Instrumentation Operating Conditions 4.5 Limiting Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances for 143 Kewaunee Reactor Protection System (RPS) Instrumentation to Support the Setpoint Control Program 4.6 Limiting Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances for 170 Kewaunee Engineered Safety Features Actuation System (ESFAS) Instrumentation to Support Setpoint Control Program 4.7 Limiting Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances for 186 Kewaunee Instrumentation Associated with LCOs 3.3.5, 3.3.6, and 3.3.7 to Support the Setpoint Control Program

5.0 REFERENCES

191

EE-0116 Page 3 of 199 Revision 5

1.0 INTRODUCTION

1.1 Purpose The purpose of this document is to provide a comprehensive and controlled reference which details the design basis for the Allowable Values that appear in North Anna Power Station Improved Technical Specifications (ITS), Kewaunee Power Station Setpoint Control Program, and the LSSS/Setting Limit Values that appear in Surry Power Station Custom Technical Specifications (CTS).

1.2 Scope

  • This document provides the basis for the Allowable Values to be used in North Anna Power Station Improved Technical Specifications, Table 3.3.1-1, Reactor Trip System Instrumentation (NAPS).
  • This document provides the basis for the Allowable Values to be used in North Anna Power Station Improved Technical Specifications, Table 3.3.2-1, Engineered Safety Feature Actuation System Instrumentation (NAPS).
  • This document provides the basis for the Limiting Safety System Settings (LSSS) to be used in Surry Power Station Custom Technical Specifications, Section 2.3, Limiting Safety System Settings, Protective Instrumentation.
  • This document provides the basis for the Setting Limit Values to be used in Surry Power Station Custom Technical Specifications, Table 3.7-4, Engineered Safety Feature System Initiation Limits Instrument Setting and Table 3.7-2, Engineered Safeguards Action Instrument Operating Conditions.

Limiting Trip Setpoints, Nominal Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances to be used in Kewaunee Power Stations Setpoint Control Program to support the conversion to Improved Technical Specifications.

  • This document provides the basis for the Engineered Safety Features Actuation System (ESFAS)

Instrumentation Functions (LCO 3.3.2) Limiting Trip Setpoints, Nominal Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances to be used in Kewaunee Power Stations Setpoint Control Program to support the conversion to Improved Technical Specifications.

  • This document provides the basis for the Loss of Offsite Power (LOOP) Diesel Generator (DG) Start Instrumentation (LCO 3.3.5) Limiting Trip Setpoints, Nominal Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances to be used in Kewaunee Power Stations Setpoint Control Program to support the conversion to Improved Technical Specifications.
  • This document provides the basis for the Containment Purge and Vent Isolation Instrumentation (LCO 3.3.6) and the Control Room Post Accident Recirculation (CRPAR) Actuation Instrumentation (LCO 3.3.7) As Found and As Left Tolerances to be used in Kewaunee Power Stations Setpoint Control Program to support the conversion to Improved Technical Specifications.

EE-0116 Page 4 of 199 Revision 5 2.0 OVERVIEW 2.1 Definitions Accuracy - A degree of conformity of an indicated value to a recognized, accepted standard value or ideal value.

Allowable Value (AV) - is the threshold value used to determine channel operability during the performance of channel functional tests and channel calibrations. The AV is the limiting as found setting for the channel trip setpoint that accounts for all of the NON-COT error components from the CSA Calculation in accordance with Methods 1 or 2 from ISA-RP67.04.02-2000 and ISA-RP67.04-Part II-1994.

Analytical Limit (AL) - The setpoint value assumed in the Safety Analysis. In the context of this document, the Analytical Limit is the same as the Safety Analysis Limit (SAL).

As Found Tolerance (AFT) - For Surry and North Anna, the As Found Tolerance is equal to the Allowable Value or Limiting Safety System Setting (LSSS)/Setting Limit listed in Technical Specifications. For Kewaunee, the As Found Tolerance is equal to the statistical combination of the rack error components and rack drift.

As Left Tolerance (ALT) - is not applicable for Surry and North Anna. For Kewaunee the As Left Tolerance is equal to the statistical combination of the rack error components minus the rack drift.

Calibrated Range - The calibration span of the sensor/transmitter as it applies to the indicated process range of the loop/system.

Channel Statistical Allowance (CSA) - The total instrument loop uncertainty (usually expressed in percent of instrument span) where non-interactive error components are combined statistically and interactive error components are summed arithmetically in accordance with Dominion Standard STD-EEN-0304 (Ref. 5.5).

The generic CSA equation and a summary of error terms are provided below in Table 2.1.

Channel Operational Test (COT) - A COT shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY of all devices in the channel required for channel OPERABILITY. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints required for channel OPERABILITY such that the setpoints are within the necessary range and accuracy. The COT may be performed by means of any series of sequential, overlapping, or total channel steps. In the context of this document, the Channel Operational Test is the same as a Channel Periodic Test or Channel Functional Test.

Instrument Loop - An arrangement or chain of modules or components as required to generate one or more protective/control signals and/or provide indication and recording functions. An Instrument Loop normally includes the following five elements; the process, a transmitter/sensor, process electronics, indications and/or automatic control elements.

EE-0116 Page 5 of 199 Revision 5 Limiting Safety System Setting (LSSS) - The LSSS is a term used in the Surry Power Station CTS to define the threshold value used to determine channel operability during the performance of channel functional tests and channel calibrations. In the context of this document, the CTS LSSS or Setting Limit used for Surry Power Station is equivalent to the ITS Allowable Value used for North Anna Power Station and the As Found Tolerance for Kewaunee.

Limiting Trip Setpoint (LTSP) - Based on RIS 2006-17 and TSTF-493, Rev. 4, the LTSP is the limiting setting for the channel trip setpoint considering all credible instrument errors associated with the instrument channel (Refs. 5.99 and 5.100).

Margin - The resultant value when the Channel Statistical Allowance (CSA) value is subtracted from the Total Allowance Value (usually expressed in percent of span or the process/signal values corresponding to these).

Module - A generic term for a Westinghouse Nuclear Instrumentation Module, Westinghouse 7300 Series PC Card, Foxboro Module, NUS Module, or a Westinghouse/Hagan 7100 Electronic Module.

Nominal Trip Setpoint (NTSP) - The desired setpoint for the variable. Initial calibration and subsequent re-calibrations should be made at the Nominal Trip Setpoint value specified in approved plant documentation.

According to RIS 2006-17 and TSTF-493, Rev. 4 (Refs. 5.99 and 5.100), the NTSP is the Limiting Trip Setpoint with margin added. The NTSP is always equal to or more conservative than the LTSP.

Operating Margin - The difference between the nominal operating value for the process parameter and the most limiting trip/alarm setpoint/control limit (usually expressed in percent of span or the process/signal values corresponding to these).

Process Range - The upper and lower limits of the operating region for a device, e.g., for a Pressurizer Pressure Transmitter, 0 to 3000 PSIG, for Steam Generator Level, 0 to 100 % Level. This is not necessarily the calibrated range of the device, e.g., for the Pressurizer Pressure Transmitter, the typical calibrated range is 1700 to 2500 PSIG.

Rack Error Components - These are the error terms associated with the process modules that are used to develop a Channel Statistical Allowance (CSA) value for a particular trip/alarm function. These rack error components are the calibration tolerances associated with the process modules for a module calibration (M1, M2 ... Mn) or (RCA & RCSA) for string calibration and an uncertainty value to account for Rack Drift (RD). These rack error components are combined statistically to determine the maximum allowable error which, ideally, should be used to determine the Allowable Value/LSSS/Setting Limit.

Safety Analysis Limit (SAL) - The setpoint value assumed in the Safety Analysis. In the context of this document, the Safety Analysis Limit is equivalent to the Analytical Limit (AL).

Span - The difference between the upper and lower range values of a process parameter or the signal values corresponding to these.

Tolerance - The allowable deviation from an ideal calculated value.

EE-0116 Page 6 of 199 Revision 5 Total Allowance - The difference between the Nominal Trip Setpoint and the Safety Analysis Limit (usually expressed in percent of span or the process/signal values corresponding to these).

Total Loop Uncertainty (TLU) - In the context of this document, the TLU is equivalent to the Channel Statistical Allowance (CSA). A summary of TLU/CSA error terms is provided in Table 2.1 below.

EE-0116 Page 7 of 199 Revision 5 Table 2.1: Channel Statistical Allowance (CSA) Equation and Error Term Definitions CSA = SE + [EA2 + PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 + (M1+M1MTE)2 +

(M2+M2MTE)2 + + (Mn+MnMTE)2 + RD2 + RTE2 + RRA2]1/2 Systematic Error (SE) Systematic Error is treated as a bias (unidirectional) and is always placed outside (NON-COT) of the radical. Examples of Systematic Error are transmitter reference leg heatup, uncorrected Sensor Pressure Effects (SPE) and the SG Mid Deck Plate bias.

Environmental Allowance (EA) Environmental Allowance is normally associated with instrument loop sensors and (NON-COT) equipment that is subjected to a HARSH environment during DBE and/or PDBE conditions. EA is made up of Insulation Resistance (IR) Effects, Radiation Effects (RE), Steam Pressure Temperature Effects (SPTE) and Seismic Mounting Effects (SME).

Process Measurement Accuracy (PMA) Process Measurement Accuracy is an allowance for non-instrument related effects (NON-COT) that directly influence the accuracy of the instrument loop. Examples of PMA are fluid stratification effects on temperature measurement and the effects of fluid density changes on level measurement.

Primary Element Accuracy (PEA) Primary Element Accuracy is an allowance for the inaccuracies of the system (NON-COT) element that quantitatively converts the measured variable energy into a form suitable for measurement.

Sensor Calibration Accuracy (SCA) Sensor Calibration Accuracy is a number or quantity that defines a limit that errors (NON-COT) will not exceed when a sensor is used under specified operating conditions, i.e.,

the calibration accuracy of the sensor.

Sensor Measuring & Test Equipment (SMTE) Sensor Measuring & Test Equipment is associated with the accuracy of the (NON-COT) Measuring and Test Equipment (M&TE) used to calibrate the loop sensor(s).

Examples of SMTE are Test Gauges and Digital Multimeters (DMM).

Sensor Drift (SD) Sensor Drift is an allowance for the change in the input versus output relationship (NON-COT) of the sensor over a period of time under specified reference operating conditions.

Sensor Pressure Effects (SPE) Sensor Pressure Effects are allowances for the steady-state pressure applied to a (NON-COT) device. Normally, SPE applies only for differential pressure devices and is associated with the change in input-output relationship due to a change in static pressure. SPE is divided into two terms, Static Pressure Zero Effect (SPZE) and Static Pressure Span Effect (SPSE).

Sensor Temperature Effects (STE) Sensor Temperature Effect is an allowance for the effects of changes in the (NON-COT) ambient temperature surrounding the sensor.

Sensor Power Supply Effect (SPSE) Sensor Power Supply Effect is an allowance for the effects of changes in the (NON-COT) power supply voltage applied to the sensor.

Module Calibration Accuracy (M1 through Mn) Module M1 to Mn is an Allowance for the accuracy of an assembly of (COT) interconnected components that constitute an identifiable device, instrument, or piece of equipment. A module can be disconnected, removed as a unit and replaced with a spare. It has definable performance characteristics that permit it to be tested as a unit.

Module Measuring & Test Equipment (MnMTE) Module Measuring & Test Equipment is associated with the accuracy of the (NON-COT) Measuring and Test Equipment (M&TE) used to calibrate the loop module(s).

Examples of MnMTE are Decade Boxes, Digital Multimeters (DMM), Test Point Resistors (TPR), Oscilloscopes and Recorders.

Rack Drift (RD) Rack Drift is an allowance for the change in the input versus output relationship of (COT) the Rack Modules (M1 through Mn) over a period of time under specified reference operating conditions.

Rack Temperature Effect (RTE) Sensor Temperature Effect is an allowance for the effects of changes in the (NON-COT) ambient temperature surrounding the Process Racks.

Rack Readability Allowance (RRA) Rack Readability Allowance is an allowance for the inability to read analog (N/A) indicators because of parallax distortion.

EE-0116 Page 8 of 199 Revision 5 2.2 The Significance of the Allowable Value 2.2.1 Background Historically, for plants that have used Westinghouse Standardized Technical Specifications (STS) such as North Anna, two values have been provided for each Reactor Trip System (RTS) and Engineered Safety Features Actuation System (ESFAS) trip function; they are referred to as the "Nominal Trip Setpoint" and the "Allowable Value" (in the context of this document, the Allowable Value, Limiting Safety System Setting LSSS and the Setting Limit are the same). The difference in percent of span between the Nominal Trip Setpoint and the Allowable Value was calculated, in most cases, based on a summation of the errors associated with the rack components and rack drift. For linear, non-complex trip functions, this value normally worked out to be between 1.0 % and 2.0 % of span. For complex trip functions or functions that had limited margin with respect to the Safety Analysis Limit, other calculational methods were used to determine the difference between the Nominal Trip Setpoint and the Allowable Value. For plants that do not use the Westinghouse STS version of Technical Specifications such as Surry, normally only one setpoint value (assumed to be the Limiting Safety System Setting LSSS or the Setting Limit at Surry) is provided in the text with no guidance as to how to set the actual "Nominal" Trip Setpoint in the plant.

Based on the early versions of the Westinghouse STS, the original definition of the LSSS (i.e., the Allowable Value) was stated as follows:

"A setting chosen to prevent exceeding a Safety Analysis Limit".

This Allowable Value was intended to be used during monthly or quarterly Functional Testing as a "flag" such that if a bistable (comparator) Trip Setpoint exceeded this value, the protection channel would be declared inoperable and plant staff would be required to initiate corrective action. The intended significance of this value is that it is the point where if the value is exceeded, the implication is that the actual rack electronics and/or associated rack error components have exceeded the values assumed in the Channel Statistical Allowance (CSA) Calculation and consequently, the margin with respect to the Safety Analysis Limit has been reduced.

The Allowable Value takes on added significance when there is little or no retained/available margin with respect to the Safety Analysis Limit and conversely takes on reduced significance in proportion to the amount of retained/available margin.

2.2.2 Addressing Recent NRC Concerns Associated with Allowable Values Dominion Corporate I&C Engineering attended a meeting with the Nuclear Regulatory Commission (NRC) and Nuclear Energy Institute (NEI) in Rockville, MD on October 8, 2003 to evaluate NRC concerns associated with the Allowable Values used in Technical Specifications. The Allowable Values of interest are those associated with Reactor Protection System (RPS) (e.g., also known as the Reactor Trip System RTS) and Engineered Safety Features Actuation System (ESFAS) Functions that are credited in the Plant Specific Safety Analysis. The NRC expressed a basic concern at the meeting where they have identified various plants that use a method to calculate Allowable Values for RTS and ESFAS functions that will reduce or eliminate margin to the Analytical Limit (AL), i.e., also known as the Safety Analysis

EE-0116 Page 9 of 199 Revision 5 Limit (SAL). In the worst case scenario, the margin may be determined to be negative such that the protection function is operating outside of the analyzed region.

On August 13, 2003, NRC Staff met with members of the ISA 67.04 committee and other industry groups in Rockville, MD to discuss instrument setpoint methodology and lay out their position. The major area of discussion focused on the instrument setpoint methodology recommended in ISA Standard S67.04 used by many licensees for determining protection system instrumentation setpoints. Part II of the standard, not endorsed by the NRC Staff, includes three methods for calculating Allowable Values which represent the Limiting Safety System Settings (LSSS) as described in 10CFR50.36. As stated by the NRC, Methods 1 and 2 determine Allowable Values that are sufficiently conservative and are acceptable to the NRC Staff.

According to the NRC, Method 3 does not appear to provide an acceptable degree of conservatism and is of concern to the NRC Staff. In addition, there is also a disagreement between the NRC Staff and NEI/ISA/Some Industry Groups as to the meaning/intent of the LSSS. These items will be addressed in this document as they apply to Surry and North Anna.

As of August 2002 North Anna adopted Improved Technical Specifications (ITS). Within the North Anna ITS and ITS Bases, Allowable Values are explicitly defined and are uniquely associated with each RTS and ESFAS function, to include Backup Trips and Permissives. The Allowable Values specified in North Annas ITS as described in this Technical Report are based on Methods 1 or 2 from ISA-RP67.04.02-2000 and ISA-RP67.04-Part II-1994.

Surry Power Station has not adopted ITS and has decided to continue using their Custom Technical Specifications (CTS). For plants licensed before 1974, prior to the introduction of Standardized Technical Specifications (STS), the setpoints (i.e., Technical Specification Limits) included in CTS for RPS and ESFAS instrumentation were based on the plant specific setpoint study and/or based on settings provided in the Westinghouse Precautions, Limitations and Setpoints (PLS) document. The RPS and ESFAS trip setpoints specified in CTS did not include allowances for instrument uncertainties associated with channel functional testing (i.e., the COT). These allowances were left up to the licensee to deal with and justify. At the present time, this applies to Surry. In many cases, the original CTS setpoints for RPS and ESFAS instrumentation have been determined to be unacceptable based on todays standards and setpoint methodologies. To address this discrepancy, Technical Specification Change Request (TSCR) No. 318 was prepared to revise 16 Limiting Safety System Settings for the Reactor Protection System and 11 Setting Limits for the Engineered Safety Features Actuation System. The revised Limiting Safety System Settings and Setting Limits were calculated in accordance with Methods 1 or 2 from ISA-RP67.04.02-2000 and ISA-RP67.04-Part II-1994. TSCR No. 318 was approved by the USNRC via Surry Technical Specifications Amendments 261/261 dated September 23, 2008 (Serial # 080594). The revised Limiting Safety System Settings, Setting Limits, and four setpoint changes were implemented for Surry Units 1 and 2 in November of 2008.

At the present time, Kewaunee Power Station is also using Custom Technical Specifications (CTS).

Kewaunees CTS is very similar to the CTS used at Surry Power Station. Dominion has decided that Kewaunee will convert to Improved Technical Specifications (ITS) in the near future. As part of the ITS conversion, Kewaunee will remove their Reactor Protection System LSSSs, ESFAS Setting Limits (known as Allowable Values in ITS), Diesel Generator (LOOP), Containment Purge and Vent Isolation, and Control Room Post Accident Recirculation Actuation from Technical Specifications and maintain control of these and other critical limits in a Setpoint Control Program as allowed by Option B of TSTF-493,

EE-0116 Page 10 of 199 Revision 5 Revision 4 (Ref. 5.99). The Setpoint Control Program will be administered as defined in ITS, Section 5.5.16 Setpoint Control Program. Like North Anna and Surry, the Allowable Values for RPS and ESFAS Instrumentation, as administered by the Setpoint Control Program will be calculated in accordance with Methods 1 or 2 from ISA-RP67.04.02-2000 and ISA-RP67.04-Part II-1994. The Kewaunee Diesel Generator (LOOP), Containment Purge and Vent Isolation, and Control Room Post Accident Recirculation Actuation instrumentation will be handled using Methods 1 and 2 as applicable.

The following subsections will focus on the meaning/intent of the Limiting Safety System Setting (LSSS) and the Allowable Value (AV) as understood by the NRC, ISA/NEI/Various Industry Groups and Dominion.

2.2.3 The NRC Staff Position Concerning the LSSS and AV The following LSSS information is based on information from the NRC presentation to the ISA 67.04 Committee on August 13, 2003.

10CFR50.36(C)(1)(ii)(A) defines the Limiting Safety System Setting (LSSS) as the setting that must be chosen so that the automatic protective action will correct the abnormal situation before a safety limit is exceeded.

New Improved TS Bases defines allowable value (AV) to be equivalent to LSSS and defines that a channel is operable if the trip setpoint is found not to exceed the AV during the Channel Operational Test (COT).

Prior to the issuance of NRC Regulatory Issue Summary (RIS) 2006-17, the NRC Staff believed that the Allowable Value (AV) is equivalent to the Limiting Safety System Setting (LSSS). Since the issuance of RIS 2006-17 (Ref. 5.100), the NRCs staff position is that the Limiting Trip Setpoint (LSP) protects the Safety Limit (SL) and relationship between the Allowable Value and the LSSS has been expanded upon as discussed in Section 2.2.6.(1) 2.2.4 The ISA/NEI/Various Industry Groups Position Concerning the LSSS and AV The following information is based on the ISA 67.04 Subcommittee handout from August 13, 2003.

Position Statements

  • The difference between the Allowable Value (AV) and the Analytical Limit (AL) is not a direct defense of the AL.
  • The Trip Setpoint (TSP) protects the AL.

(1) There is a difference in the terminology and abbreviations used in TSTF-493, Rev. 4 versus RIS 2006-17 with respect to the Limiting Trip Setpoint and the Safety Limit.

EE-0116 Page 11 of 199 Revision 5 Summary

  • The AV, based on a portion of the errors, does not invalidate the TSP.
  • The AV validates an error contribution assumption via periodic surveillance testing.
  • As long as the AV is not exceeded, the channel is OPERABLE.
  • During Surveillance Testing, the AV serves as the LSSS.

In summary, ISA/NEI/Various Industry Groups believe that the Allowable Value (AV) is equivalent to the Limiting Safety System Setting (LSSS). However, their position is that the TSP is used to protect the Analytical Limit (AL). All of the items listed above are true, with the exception of The TSP protects the AL. This is the statement that is under dispute.

Since August of 2003, the Industry has been developing Technical Specification Task Force Improved Standard Technical Specifications Change Traveler TSTF-493. This document addresses the agreement made between the USNRC and the industry concerning the issues listed above. Dominions implementation of the requirements set forth in TSTF-493, Revision 4 (Ref. 5.99) as they apply to Kewaunee Power Station will be addressed in Sections 2.2.6 and 3.5.

2.2.5 The Dominion Position Concerning the LSSS and AV for North Anna and Surry Information Intentionally Removed Specific to North Anna Power Station and Surry Power Station Only

EE-0116 Page 12 of 199 Revision 5 Information Intentionally Removed Specific to North Anna Power Station and Surry Power Station Only 2.2.6 The Dominion Position Concerning the LSSS and AV for Kewaunee Dominion has decided to adopt Improved Technical Specifications (ITS) for Kewaunee. As part of the ITS conversion, Dominion has chosen to implement Option B of TSTF-493, Revision 4 (Ref. 5.99). TSTF-493, Revision 4, Option B allows for the relocation of Reactor Protection System RPS (also known as the Reactor Trip System RTS) and Engineered Safety Features Actuation System - ESFAS (also known as Engineered Safety Features - ESF) Allowable Values (also known as the Limiting Safety System Settings - LSSSs or Setting Limits) from Section 3.3 of Technical Specifications to a Licensee controlled program as defined in ITS Section 5.5.16. In addition, the Diesel Generator (LOOP), Containment Purge and Vent Isolation, and Control Room Post Accident Recirculation Actuation instrumentation will also be relocated to the Licensee controlled program as defined in ITS Section 5.5.16. To implement TSTF-493, Option B, Dominion will incorporate the relevant positions taken by the industry as detailed in TSTF-493, Revision 4 and those taken by the USNRC as detailed in NRC Regulatory Issue Summary 2006-17, Dated September 19, 2006 (Refs. 5.99 and 5.100) into the Setpoint Control Program in accordance with ITS Section 5.5.16.

New and/or revised terminology and requirements have been incorporated into TSTF-493 and NRC Regulatory Issue Summary (RIS) 2006-17 that are to be used for the determination of RPS and ESFAS Setpoints. The new terminology and requirements detailed in TSTF-493, Revision 4 and RIS 2006-17 will be incorporated into Kewaunees Setpoint Control Program as described in ITS Section 5.5.16. In addition to the new terminology and requirements, the USNRC has taken the position that the Limiting Trip Setpoint (LTSP) protects the Safety Limit (SL) (Ref. 5.100). This revised position is a change from the historical definition of the Allowable Value as delineated in Standardized Technical Specifications

EE-0116 Page 13 of 199 Revision 5 (STS), i.e., "A setting chosen to prevent exceeding a Safety Analysis Limit" (Ref. 5.3). Since the Limiting Trip Setpoint (LTSP) accounts for all credible instrument errors associated with the instrument channel, it is a more conservative setting than the associated Allowable Value as defined in Section 3.5. With respect to Kewaunees conversion to ITS, Dominion agrees with this revised position based on explanations and guidance provided in TSTF-493, Revision 4 and RIS 2006-17.

Like North Anna and Surry, Kewaunees Setpoint Methodology is based on Methods 1 or 2 from ISA-RP67.04.02-2000 and ISA-RP67.04-Part II-1994. Using Methods 1 or 2 will ensure that the Allowable Value (equivalent to the Minimum or Maximum Allowable Value for Surry and North Anna) will account for all credible instrument and process errors that are not tested or quantified during the performance of the Channel Operational Test (COT). This Setpoint Methodology addresses the basic NRC concern brought up back in 2003 that Method 3 (used by some Licensees to determine Allowable Values) as described in ISA-RP67.04.02-2000 and ISA-RP67.04-Part II-1994 may yield Allowable Values that will not protect the Safety Limit under all postulated conditions. In addition to using Methods 1 or 2, Kewaunees Setpoint Methodology will incorporate the revised terminology and additional requirements imposed by TSTF-493, Revision 4 and RIS 2006-17. A detailed discussion of Kewaunees Setpoint Methodology incorporating the revised terminology and requirements from TSTF-493 and RIS 2006-17 is provided in Section 3.5.

EE-0116 Page 14 of 199 Revision 5 3.0 METHODOLOGY 3.1 Introduction Many Westinghouse Plants continue to use Westinghouse or other Engineering Firms to perform some or all of their Safety Analysis Functions. In addition, Westinghouse has also performed the RPS (RTS) and ESFAS Setpoint Study for many of their plants. Typically, the Setpoint Study for these plants included the development of Channel Statistical Allowance (CSA) Calculations for Primary and some of the Backup RTS and ESFAS Trip Functions. Derived from these Setpoint Studies and CSA Calculations are the Allowable Values that appear in various versions of Standardized Technical Specifications (STS). For the Westinghouse Plants that use Custom Technical Specifications (CTS), the setpoint values specified for RPS and ESFAS Trip Functions are not defined as Allowable Values and typically, they are the same setpoint values as those found in the original Precautions, Limitations and Setpoints (PLS) Document for that particular plant. This was the case for Surrys Custom Technical Specifications until the implementation of Technical Specifications Change Request No. 318 ultimately resulting in TS Amendments 261/261 for Units 1 and 2, respectively (Ref. 5.119).

Dominion is unique in the fact that a majority of the UFSAR Chapter 14 (Surry and Kewaunee) and Chapter 15 (North Anna) Safety Analysis is performed in house by the Corporate Nuclear Analysis & Fuels Department. In addition, Channel Statistical Allowance Calculations for Primary and Backup RPS (RTS) and ESFAS Trip Functions are performed in house by the Corporate Electrical/I&C/Computers Department. Because Dominion performs their own Safety Analysis and CSA Calculations, the methodology used to determine Improved Technical Specifications (NUREG-1431 ITS) Allowable Values for North Anna, As Found Tolerances for Kewaunee, and LSSS/Setting Limits for Surry Custom Technical Specifications will be similar and in some cases more conservative than that used by Westinghouse in the past to determine Allowable Values for later versions of Standardized Technical Specifications. In addition, the methods used in this Technical Report to calculate the limiting values for North Anna, Kewaunee, and Surry will be consistent with the requirements of Methods 1 or 2 as described in ISA-RP67.04.02-2000 (Ref 5.43).

3.2 Functional Groups for RPS (RTS) and ESFAS Instrumentation.

Based on Dominion Technical Report NE-0994 (Ref. 5.1), the Reactor Protection System (RPS)/Reactor Trip System (RTS) and the Engineered Safety Features Actuation System (ESFAS) Instrumentation at North Anna, Kewaunee, and Surry can be divided into two major categories, i.e., Primary Trip Functions and Backup Trip Functions. Primary Trip Functions are credited in the Plant Safety Analysis and have an associated Analytical Limit (i.e., Safety Analysis Limit or Safety Limit). Backup Trip Functions are not credited in the Plant Safety Analysis but are included in the Reactor Protection System and the Engineered Safety Features Actuation System to enhance the overall effectiveness of the system.

Primary Trip Functions include the following:

  • Primary ESFAS Actuation Functions
  • Primary ESFAS Permissives

EE-0116 Page 15 of 199 Revision 5 Backup Trip Functions include the following:

  • Backup ESFAS Permissives In addition to the above, there are three basic functional groups of Westinghouse Nuclear Instrumentation System (NIS), Foxboro H-Line, NUS Replacement Modules, Westinghouse/Hagan 7100, and Westinghouse 7300 Instrumentation that develop the majority of the RPS/RTS and ESFAS trips. These basic functional groups are divided into the three categories listed below:
1. Single parameter protection function
2. Dual parameter protection function
3. Multiple parameter protection function (i.e., more than two process parameters)

Different methods are used to calculate or validate the Allowable Values for North Anna, As Found Tolerances for Kewaunee, and LSSS/Setting Limits for Surry depending on whether the function is considered to be Primary or Backup. In addition, the functional group category will also effect how the Allowable Value, As Found Tolerance or LSSS/Setting Limit is calculated. Some examples of functional groups are given below.

Single Parameter Protection Functions

  • Containment Hi-1, Hi-2 and Hi-3 (North Anna only) Pressure ESFAS initiation
  • Compensated Low Steam Line Pressure ESFAS initiation
  • Surry High Steam Flow in 2/3 Lines ESFAS initiation
  • Surry High P Steam Line vs. Steam Header ESFAS initiation
  • North Anna High P Steam Line vs. Steam Line ESFAS initiation Multiple Parameter Protection Functions

EE-0116 Page 16 of 199 Revision 5 Single Parameter Protection Functions North Anna The Nuclear Steam Supply System (NSSS) Protection and Control System at North Anna is made up of the Westinghouse Nuclear Instrumentation System (NIS) and the Westinghouse 7300 Series Process Control System. Most of the RTS and ESFAS trips generated from these systems are single parameter protection functions. Figures 3.2-1 and 3.2-2 illustrate the configuration of the Westinghouse NIS and the 7300 Process Control System.

Westinghouse Nuclear Instrumentation System - Power Range Reactor Trips NI301 QU Current Meter Amps NI303 BF 3 Detector A

% Power Meter NC306 To High Flux SSPS Upper Flux Test Switch RX Trip Trains Bistable A&B

+/- 1.0 %

+/- 1.0 %

NQ303 NM310 High Voltage Summing &

Power Supply Level Amplifier BF 3 Detector B NC305 To Test Switch Low Flux SSPS RX Trip Lower Flux Trains Bistable A&B

+/- 1.0 %

Amps Far NI302 Near Field Rack QL Current Meter Rack Field Figure 3.2-1

EE-0116 Page 17 of 199 Revision 5 Refer to Figure 3.2-1 :

CSA Calculations performed for Reactor Trips generated by NIS typically include rack error terms associated with the meter indications (i.e., Amps, % Full Power, Counts per Second, etc.) and the bistables that generate the trip.

In the case of the Power Range High Flux Reactor Trip as shown on Figure 3.2-1, the rack error terms as defined in CSA Calculation EE-0063 (Ref. 5.15) are :

(M1 + M1TE) + (M5 + M5MTE) + RD + RTE Where: M1 = Module 1 Summing and Level Amplifier = + 0.100 %

M1MTE = Module 1 Measuring and Test Equipment = + 0.110 %

M5 = Module 5 Bistable Relay Driver = + 0.833 %

M5MTE = Module 5 Measuring and Test Equipment = + 0.943 %

RD = Rack Drift = + 1.000 %

RTE = Rack Temperature Effects = + 0.500 %

Westinghouse 7300 Process Control System Low Reactor Coolant Flow Reactor Trip A B FS-414 FQ-414 FS-414-1 FC-414 Ch. Test Switch 39.9 VDC RC Flow L-NE B/S Test Switch RC Low Flow Loop Power Supply RX Trip FT-414 4 - 20 mADC (Non-Isolated) 0 - 10 VDC 24 VDC Analog Comparator Output M2 M1 TO RC Flow BS-1 TJ TP SSPS Transmitter Trains Foxboro E13DH or A& B (NCTG01) (NLPG02 or NLPG05) (NALG01) (NCTG01)

Rosemount 1153

+/- 0.75 % +/- 0.1 % +/- 0.25 %

+/- 0.25 % (MAX) Near Far Rack (MAX) Rack Field Field Figure 3.2-2 Refer to Figure 3.2-2 :

CSA Calculations performed for Reactor Trips generated by the Westinghouse 7300 Process Control System include rack error terms associated with the PC Cards that perform signal modification and the bistables that generate the trip.

In the case of the Low Reactor Coolant Flow Reactor Trip as shown on Figure 3.2-2, the rack error terms as defined in CSA Calculation EE-0060 (Ref. 5.21) are :

(M1 + M1MTE) + (M2 + M2MTE) + RD + RTE

EE-0116 Page 18 of 199 Revision 5 Where: M1 = Module 1 Loop Power Supply = + 0.100 %

M1MTE = Module 1 Measuring and Test Equipment = + 0.153 %

M2 = Module 2 Analog Comparator Bistable = + 0.250 %

M2MTE = Module 2 Measuring and Test Equipment = + 0.030 %

RD = Rack Drift = + 1.000 %

RTE = Rack Temperature Effects = + 0.500 %

These rack error terms along with other error terms from the CSA Calculation will be used to validate the existing Allowable Values at North Anna or to calculate revised Allowable Values, if necessary.

Surry The NSSS Protection and Control System at Surry uses the same Westinghouse Nuclear Instrumentation System (NIS) as North Anna. However, a majority of NSSS Protection and Control is developed from the Westinghouse/Hagan 7100 Series Process Control System (using NUS Replacement Modules for some functions). Like North Anna, most of the RPS and ESFAS trips generated from these systems are single parameter protection functions. For the Westinghouse NIS, Figure 3.2-1 is also applicable for Surry. Figure 3.2-3 illustrates the configuration of the Westinghouse/Hagan 7100 Process Control System for a single input protection function.

Westinghouse 7100 Process Control System Low Reactor Coolant Flow Reactor Trip Test Point Resistor FS-414 FC-414 A B FS-414-1 TP RC Low Flow L-NE B/S Test Switch RX Trip I/V Block FT-414 Signal Comparator 118 VAC 1 - 5 VDC Module 4 - 20 mADC RCAcompar Ch. TO RC Flow Test TJ BS-1 Transmitter Test Jack RPS Relay 131-118 or NUS Logic Rosemount 1153

+/- 0.5 % FQ-414 +/- 0.5 %

38 VDC RC Flow Loop Power Supply Module Technipower PM-38 or NUS

+/- 0.0 %

Figure 3.2-3 Refer to Figure 3.2-3 :

CSA Calculations performed for Reactor Trips generated by the Westinghouse/Hagan 7100 Process Control System also include rack error terms associated with the modules that perform signal modification and the bistables that generate the trip. The Westinghouse 7100 Process Control System mainly operates using current loops where the power supplies are not used as signal converters. In many cases, for a single parameter protection function, the only rack module that will have a tolerance

EE-0116 Page 19 of 199 Revision 5 associated with it will be the Signal Comparator (i.e., the Bistable). In the case of Surrys Low Reactor Coolant Flow Reactor Trip as shown in Figure 3.2-3, the rack error terms from CSA Calculation EE-0183 (Ref. 5.34) are :

(M5 + M5MTE) + RD + RTE Where: M5 = Rack Comparator Setting Accuracy = + 0.50 %

M5MTE = Rack Measuring and Test Equipment = + 0.15 %

RD = Rack Drift = + 1.00 %

RTE = Rack Temperature Effects = + 0.50 %

Note the difference between North Annas rack error terms compared with the rack error terms listed above for Surry. The error terms for the Loop Power Supply are not included in Surrys CSA Calculation because it is not used as a signal converter.

Kewaunee The NSSS Protection and Control System at Kewaunee uses the same Westinghouse Nuclear Instrumentation System (NIS) as does North Anna and Surry for Power Range. Most of the NSSS Protection and Control is developed from the Foxboro H-Line Process Control System (using NUS Replacement Modules for some functions). Like North Anna and Surry, most of the RPS and ESFAS trips generated from these systems are single parameter protection functions. For the Westinghouse Power Range NIS, Figure 3.2-1 is also applicable for Kewaunee. Figure 3.2-4 illustrates the configuration of the Foxboro H-Line Process Control System for a single input protection function.

Foxboro H-Line Process Control System Low Reactor Coolant Flow Reactor Trip 4872201 FQ-411 RC Flow 40 - 200 mVDC Loop Power TP/FQ-414 Supply Module

+ -

10 H/610AC-0 or NUS

+/- 0.0 %

FS-411 DB-6 4 - 20 mADC 23024 TJ FT-411 + F/411 C D

- 250 4872202 L-NE FC-411 RC Flow RC Low Flow 120 VAC Transmitter RX Trip Rosemount 1154 Channel 270 Bistable Bistable Test To RPS

+/- 0.25 % Test Switch Relay Logic H/63U-AC-OHAA or To Other Loop NUS Components +/- 0.5 %

Figure 3.2-4

EE-0116 Page 20 of 199 Revision 5 Refer to Figure 3.2-4 :

CSA Calculations performed for Reactor Trips generated by the Foxboro H-Line Control System also include rack error terms associated with the modules that perform signal modification and the bistables that generate the trip. The Foxboro H-Line Process Control System mainly operates using current loops where the power supplies are not used as signal converters. In many cases, for a single parameter protection function, the only rack module that will have a tolerance associated with it will be the Bistable Module.

In the case of Kewaunees Low Reactor Coolant Flow Reactor Trip as shown in Figure 3.2-4, the rack error terms from CSA Calculation C10819 (Ref. 5.96) are :

(M2BISTABLE + M2MTE) + RD + RTE Where: M2BISTABLE = Rack Bistable Setting Accuracy = + 0.50 %

M2MTE = Rack Measuring and Test Equipment = + 0.20 %

RD = Rack Drift = + 1.00 %

RTE = Rack Temperature Effects = + 0.50 %

Note the difference between North Annas rack error terms compared with the rack error terms listed above for Kewaunee. The error terms for the Loop Power Supply are not included in Kewaunees CSA Calculation because it is not used as a signal converter.

Dual Parameter Protection Functions Westinghouse 7300 Process Control System High Steam Flow in 2/3 Lines ESFAS - Channel 3 FQ-474 FC-474 A B FS-474 FS-474-1 Steam Flow 0 - 10 VDC High Steam Flow Ch. Test Switch 39 .9 VDC Loop Power Supply ESFAS L-NE B/S Test Switch (Non-Isolated) Analog Comparator FT-474 4 - 20 mADC 24 VDC Output M15 Steam Flow M1 BS-1 TO Transmitte r TJ TP SSPS Trains Rosemount 115 3 (NLPG0 2 or NLPG05) (NALG01) A &B (NCTG01) (NCTG01)

+/- 0 .5 % +/- 0.1 %

+/- 0.5 %

+/- 0.2 5 %

(MAX)

(MAX)

PQ-446 PS-446 PM-446B Ch. Tes t Switch Turbine Load High Stea m Flow 39.9 VDC Loop Power Supply (Non-Isolated) Setpoint Summing PT-44 6 4 - 20 mADC 0 - 10 VDC Amplifier 0 - 10 VDC Output Turbine Loa d M14 TJ TP M13 Tr ansmitter (NLPG02 or NLPG05)

Rose mount 1 153 (NSAG02)

(NCTG02) +/- 0.1 %

+/- 0.50 % +/- 0.5 %

+/- 0.25 %

(MAX)

(MAX)

Figure 3.2-5

EE-0116 Page 21 of 199 Revision 5 Figure 3.2-5 illustrates a typical dual input protection function for North Anna. Channel Statistical Allowance Calculations for dual parameter protection functions are different than single parameter functions. For example, there are more rack error terms associated with the development of the trip than a single parameter function. The rack error terms associated with North Annas High Steam Flow in 2/3 Lines ESFAS trip based on Calculation EE-0736 (Ref. 5.23) are given below :

(M1 + M1MTE) + (M13 + M13MTE) + (M14 + M14MTE) + (M15 + M15MTE) + RD + RTE Where: M1 = Steam Flow Loop Power Supply Accuracy = + 0.10 %

M1MTE = Module M1 Measuring and Test Equipment = + 0.153 %

M13 = Turbine Load Loop Power Supply Accuracy = + 0.10 %

M13MTE = Module M13 Measuring and Test Equipment = + 0.153 %

M14 = High Steam Flow Setpoint Summator Accuracy = + 0.50 %

M14MTE = Module M14 Measuring and Test Equipment = + 0.042 %

M15 = High Steam Flow Comparator Setting Accuracy = + 0.50 %

M15MTE = Module M15 Measuring and Test Equipment = + 0.042 %

RD = Rack Drift = + 1.00 %

RTE = Rack Temperature Effects = + 0.50 %

The rack error terms described in the example above along with other error terms from the CSA Calculation will be used to validate the existing Allowable Values at North Anna or to calculate revised Allowable Values, if necessary. The configuration of dual parameter protection functions at Surry is similar to North Annas. The major differences between the rack error components for both plants are based on the process control equipment as illustrated above for single input protection functions.

Multiple Parameter Protection Functions Kewaunee There are three multiple parameter protection functions at North Anna and Kewaunee, and four multiple parameter functions at Surry. Figure 3.2-6 is a block diagram that illustrates Kewaunees Overtemperature T Reactor Trip configuration (note that Overpower T and Low TAVG are also shown on the drawing). The configuration of North Annas and Surrys Overtemperature T Reactor Trip is similar, noting that the process control equipment is different.

As can be seen from Figure 3.2-6, Kewaunees Overtemperature T Reactor Trip function is derived from five process parameters, they are :

  • THOT
  • TCOLD
  • Pressurizer Pressure
  • Function of Delta Flux (FI) made up of Upper Flux (QU) and Lower Flux (QL)

EE-0116 Page 22 of 199 Revision 5 Kewaunee Power Station Overtemperature T Reactor Trip TE-401A Delta T DB Box TM -405R TT-401A DB-1 Foxboro E/E DB Box Foxboro or NUS Lead/Lag Unit DB-2 Rdf RTD R/E Converter Delta T (Delta T) Delta T Delta T (Thot) (Thot) M 1 M3 TE-401B TM -401BB DB Box TM -401-O TT-401B Foxboro E/I DB-3 Foxboro OR NUS Foxboro or NUS TAVG Lead/Lag Unit Impulse Lead/

R/E Converter Rdf RTD (TAVG) TAVG Lag Unit (TAVG)

(Tcold) M 2 TC-401A/D (Tcold) M4 M5 Foxboro or NUS Lo-Lo Stm Line Isol TAVG Bistable Stm Line M8 Isolation TM -401V TAVG Foxboro OPDT SP2 Summator Pressurizer M6 Pressure TAVG TC-401F CH. 1 Foxboro or NUS Low TAVG FRV Close FRV PT-429 PQ-429 DB Box TM -401B Bistable Closure Rosemount Foxboro or NUS DB-7 Foxboro OTDT M9 Model Pow er Supply SP1 Lead/Lag TAVG 1154SH9 M 10 PZR Unit M 7 DB Box TC-405A/B DB-4 W DAM 9000 QU OPDT OPDT Bistable RX Trip TAVG Overpow er Delta T SP NM 306 M 17 TC-405L W

Foxboro or NUS Isolation Qu > Ql Controller DB Box Amp FDQ M 13 DB-6 M 11 TM -401T Qu Foxboro Delta Q TC-405C/D Signal Selector W DAM 9000 OTDT DB Box M 15 OTDT Bistable RX Trip DB-5 Overtemperature Delta T SP QL M 18 Ql OTDT STPT NM 307 TC-401R W TM -401U Foxboro or NUS Isolation FDQ Ql > Qu Controller Foxboro Delta Q Amp M 14 Current Source M 12 M 16 Figure 3.2-6 The Overtemperature T Reactor Trip function is further broken down into channels as defined below :

  • T Channel, made up of THOT and TCOLD
  • TAVG Channel, made up of THOT and TCOLD
  • Pressurizer Pressure Channel
  • Function of Delta Flux (FI), made up of QU and QL Because there are five inputs to Kewaunees Overtemperature T function, the rack error components will be grouped as channel inputs versus a string of modules as shown above for the Dual Parameter Function example. This type of assessment will yield a conservative and valid Allowable Value (for Kewaunee, the Allowable Value will be the As Found Tolerance) using the four step method described in Sections 3.4 and 3.5 (Section 3.5 is Kewaunee specific). CSA Calculation C11865 (Ref. 5.94) was performed using a module calibration method, which for a multiple-parameter function will result in a very conservative CSA value. However, using a module calibration method for a complex, multiple-parameter function will result in an Allowable Value, LSSS/Setting Limit, or As Found Tolerance that

EE-0116 Page 23 of 199 Revision 5 is non-conservative. The rack error components for each Overtemperature T input channel are given below.

T Channel = (RCA1 + RMTE1) + RD1 + RTE1 TAVG Channel = (RCA2 + RMTE2) + RD2 + RTE2 Pressurizer Pressure Channel = (RCA3 + RMTE3) + RD3 + RTE3 FI Channel = (RCA4 + RMTE4) + RD4 + RTE4 OTT Setpoint = (RCA5 + RMTE5)

OTT Bistable = (RCSA + RMTE6)

Where:

RCA1 = T Channel Calibration Accuracy = + 0.707 % (M3)

RMTE1 = T Channel Rack Measuring and Test Equipment = + 0.173 % (M3MTE)

RD1 = T Channel Rack Drift = + 1.00 %

RTE1 = T Channel Rack Temperature Effect = + 0.50 %

RCA2 = TAVG Channel Calibration Accuracy = + 0.707 % (M4)

RMTE2 = TAVG Channel Rack Measuring and Test Equipment = + 0.245 % (M4MTE)

RD2 = TAVG Channel Rack Drift = + 1.00 %

RTE2 = TAVG Channel Rack Temperature Effect = + 0.50 %

RCA3 = Pressurizer Pressure Channel Calibration Accuracy = + 0.00 %

RMTE3 = Pressurizer Pressure Channel Rack Measuring and Test Equipment = + 0.0 %

RD3 = Pressurizer Pressure Channel Rack Drift = + 0.00 %

RTE3 = Pressurizer Pressure Channel Rack Temperature Effect = + 0.00 %

RCA4 = FI Channel Calibration Accuracy = + 0.50 % (M15)

RMTE4 = FI Channel Rack Measuring and Test Equipment = + 0.346 % (M15MTE)

RD4 = FI Channel Rack Drift = + 1.00 %

RTE4 = FI Channel Rack Temperature Effect = + 0.50 %

RCA5 = OTT Setpoint Summator Calibration Accuracy = + 0.50 % (M7)

RMTE5 = OTT Setpoint Summator Rack Measuring and Test Equipment = + 0.374 %

(M7MTE)

RCSA = OTT Reactor Trip Bistable = + 0.50 % (M18)

RMTE6 = OTT Reactor Trip Bistable Rack Measuring and Test Equipment = + 0.224 %

(M18MTE)

Some of the error terms listed above will be used to determine the Allowable Value (i.e., the As Found Tolerance) for Kewaunees Overtemperature T Reactor Trip. Similar error terms will be used throughout this document to evaluate the other multiple parameter protection functions at both plants.

EE-0116 Page 24 of 199 Revision 5 3.3 The Instrumentation, Systems and Automation Society (ISA) Methodologies Used to Calculate Allowable Values The following base line parameters will be used to illustrate how the Allowable Value is calculated using Methods 1, 2 and 3 from ISA-RP67.04.02-2000 and ISA-RP67.04-Part II-1994.

Analytical Limit (AL) = 6.00 PSIG Total Instrument Loop Uncertainty (TLU) = 1.39 PSIG Calculated Instrument Uncertainties used for COT (COT) = 1.10 PSIG Calculated Instrument Uncertainties not used for COT (NON-COT) = 0.85 PSIG Notes:

1. In the context of this document, the Analytical Limit (AL), Safety Limit (SL), and the Safety Analysis Limit (SAL) have the same meaning.
2. In the context of this document, Total Instrument Loop Uncertainty (TLU) and the Channel Statistical Allowance (CSA) have the same meaning.
3. COT means Channel Operational Test.
4. COT Instrument Uncertainties are made up of the portion of the loop that is tested during the COT.

For Surry, Kewaunee, and North Anna, these error components are:

  • Rack or Module Calibration Accuracy (RCA or M1, M2 ... Mn)
  • Rack Comparator Setting Accuracy or Comparator Module Calibration Accuracy (RCSA or Mn)
  • Rack Drift (RD)
5. NON-COT Instrument Uncertainties are made up of the portion of the loop that is not tested during the COT. For Surry, Kewaunee, and North Anna, these error components may include:
  • Systematic Error (SE)
  • Environmental Allowance (EA)
  • Process Measurement Accuracy (PMA)
  • Primary Element Accuracy (PEA)
  • Sensor Calibration Accuracy and Sensor Measuring and Test Equipment (SCA + SMTE)
  • Sensor Drift (SD)
  • Sensor Pressure Effect(s) (SPE)
  • Sensor Temperature Effect (STE)
  • Sensor Power Supply Effect (SPSE)
  • Rack Measuring and Test Equipment (RMTE or M1MTE, M2MTE ... MnMTE)
  • Rack Temperature Effect (RTE)

EE-0116 Page 25 of 199 Revision 5 3.3.1 Method 1 Method 1 has been evaluated by the NRC Staff and was found to be an acceptable method to be used to calculate Allowable Values. Method 1 uses a TLU equal to 1.39 PSIG. The TLU was arrived at statistically using the Square Root Sum of the Squares (SRSS) method of combining channel error components. This is an accepted industry standard and is used here at Dominion Virginia Power. The channel error components used for the COT are equal to 1.10 PSIG and the error components used for the NON-COT are equal to 0.85. With a TLU equal to 1.39 PSIG and NON-COT errors equal 0.85 PSIG, then statistically, the COT error would be equal to 1.10 PSIG as shown below.

[(0.85)2 + (1.10)2] 1/2 = 1.39 or [(1.39)2 - (0.85)2] 1/2 = 1.10 If the COT error allowance were to be removed from the TLU, the statistical combination of the NON-COT error allowances would be equal to 0.85 PSIG. This means that the LSSS would have to be set such that the margin of 0.85 PSIG is maintained between the AV and the AL. To accomplish this using a COT error allowance of 1.10 PSIG, a determinant assessment must be used such that the COT allowance can only be equal to the TLU minus the NON-COT allowance, i.e., COT = 1.39 PSIG - 0.85 PSIG = 0.54 PSIG. In Method 1, the user decides that for the Channel Operational Test, the full COT allowance of 1.10 PSIG is to be retained. To maintain the full COT error allowance, the actual trip setpoint (ACT SP) is set below the calculated trip setpoint (CAL SP). Note that the difference between the CAL SP and the Allowable Value (AV) is 0.54 PSIG. The remainder of the desired COT allowance of 1.10 PSIG is obtained by lowering the ACT SP below the CAL SP by 0.56 PSIG to yield the ACT SP value of 4.05 PSIG. Method 1 ensures that the full NON-COT allowance of 0.85 PSIG is available under all conditions for the non-tested channel error components.

METHOD 1:

AL = 6.00 PSIG NON COT = 0.85 TLU = 1.39 AV = 5.15 PSIG COT = 1.10 CAL SP = 4.61 PSIG ACT SP = 4.05 PSIG LEGEND: TLU = TOTAL LOOP UNCERTAINTY AL = ANALYTICAL LIMIT (SAL) AV = ALLOWABLE VALUE NON COT = NON TESTED LOOP UNCERTAINTY COT = TESTED LOOP UNCERTAINTY CAL SP = CALCULATED SETPOINT ACT SP = ACTUAL SETPOINT Figure 3.3-1

EE-0116 Page 26 of 199 Revision 5 3.3.2 Method 2 Method 2 has been evaluated by the NRC Staff and was found to be an acceptable method to be used to calculate Allowable Values. Method 2 is essentially the same as Method 1 with the exception that the ACT SP is set equal to the CAL SP (i.e., 4.61 PSIG). This method does not allow for the full value of the COT error components as determined in the TLU (i.e., CSA Calculation). In some cases, this could cause the plant to find the AS FOUND Trip Setpoint outside of the AV more often than would be the case using Method 1. Like Method 1, Method 2 ensures that the statistical combination of the NON-COT error allowances (equal to 0.85 PSIG) is maintained between the AV and the AL under all conditions.

METHOD 2:

AL = 6.00 PSIG NON COT = 0.85 TLU = 1.39 AV = 5.15 PSIG COT = 0.54 CAL & ACT SP = 4.61 PSIG LEGEND: TLU = TOTAL LOOP UNCERTAINTY AL = ANALYTICAL LIMIT (SAL) AV = ALLOWABLE VALUE NON COT = NON TESTED LOOP UNCERTAINTY COT = TESTED LOOP UNCERTAINTY CAL SP = CALCULATED SETPOINT ACT SP = ACTUAL SETPOINT Figure 3.3-2 3.3.3 Method 3 Method 3 has been evaluated by the NRC Staff and was found to be an unacceptable method to be used to calculate Allowable Values. Method 3 has been used to calculate the Allowable Value in many Westinghouse Plants that used early versions of Standardized Technical Specifications (STS) as discussed above in Section 3.1. Using a determinant assessment, Method 3 does not ensure that the full NON-COT uncertainty allowance is maintained between the AV and the AL. To ensure that the NON-COT uncertainty allowance is maintained under all conditions, the AV must be set for < 5.15 PSIG. As can be seen from the illustration below, the AV using Method 3 is set for 5.71 PSIG, i.e., CAL SP/ACT SP + COT

= 5.71 PSIG. If the rack error components are allowed an offset of 1.10 PSIG before the channel is declared INOPERABLE, then the allowance for the NON-COT uncertainty is decreased to 0.29 PSIG. If the AS FOUND COT error was found to be (+) 1.05 PSIG and the AS FOUND NON-COT error was determined to be (+) 0.85 PSIG, then the channel trip function would have exceeded the Analytical Limit (i.e., SAL) and should be declared INOPERABLE. However, in accordance with Technical Specifications, the channel does not have to be declared INOPERABLE until the AS FOUND Trip Setpoint exceeds the Allowable Value. This is the concern that the NRC Staff has with Method 3. In the case of Method 3 using

EE-0116 Page 27 of 199 Revision 5 a determinant assessment, the AV does not protect the AL and does not identify an inoperable channel under all operating conditions.

METHOD 3:

AL = 6.00 PSIG NON COT = 0.29 TLU = 1.39 AV = 5.71 PSIG COT = 1.10 CAL & ACT SP = 4.61 PSIG LEGEND: TLU = TOTAL LOOP UNCERTAINTY AL = ANALYTICAL LIMIT (SAL) AV = ALLOWABLE VALUE NON COT = NON TESTED LOOP UNCERTAINTY COT = TESTED LOOP UNCERTAINTY CAL SP = CALCULATED SETPOINT ACT SP = ACTUAL SETPOINT Figure 3.3-3 3.3.4 Method 3 with Additional Margin Method 3 using additional margin for the ACT SP has been evaluated by the NRC Staff and was found to be an unacceptable method to be used to calculate Allowable Values. Method 3 with additional margin is identical to Method 3 with the exception that the ACT SP is set below the CAL SP. In the case used for this illustration, the ACT SP is set for 4.00 PSIG which provides a margin of 0.61 PSIG to the CAL SP and 1.71 PSIG to the AV. This method actually yields less conservative results than Method 3 for two reasons. First, the AV is still set for 5.71 PSIG yielding a NON-COT allowance of 0.29 PSIG. As discussed above, using a determinant assessment, the NON-COT allowance of 0.29 PSIG does not fully account for the statistical combination of the non-tested loop error components.

Second, the calculated COT allowance was determined to be 1.10 PSIG. Allowing an error of 1.71 PSIG between the ACT SP and the AV is beyond the assumptions used to develop the TLU (i.e., CSA Calculation). Allowing an error of 1.71 PSIG for the Trip Setpoint before the channel is declared INOPERABLE is inconsistent with the applicable TLU assumptions and will not ensure that the rack components are operating within the assumptions of the CSA Calculation and/or the manufacturer specifications. Also note that the difference between the ACT SP and the AV is larger than the calculated TLU for the entire channel.

EE-0116 Page 28 of 199 Revision 5 METHOD 3 WITH ADDITIONAL MARGIN:

AL = 6.00 PSIG NON COT = 0.29 TLU = 1.39 AV = 5.71 PSIG COT = 1.1 CAL SP = 4.61 PSIG ACT SP = 4.00 PSIG LEGEND: TLU = TOTAL LOOP UNCERTAINTY AL = ANALYTICAL LIMIT (SAL) AV = ALLOWABLE VALUE NON COT = NON TESTED LOOP UNCERTAINTY COT = TESTED LOOP UNCERTAINTY CAL SP = CALCULATED SETPOINT ACT SP = ACTUAL SETPOINT Figure 3.3-4

EE-0116 Page 29 of 199 Revision 5 3.4 Methodology for Determining North Anna Allowable Values and Surry LSSS/Setting Limits Information Intentionally Removed Specific to North Anna Power Station and Surry Power Station Only

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EE-0116 Page 39 of 199 Revision 5 3.5 Methodology for Determining Kewaunees Allowable Value and Limiting Trip Setpoint Based on TSTF-493 and RIS 2006-17 Kewaunees setpoint methodology is identical to that of Surry and North Anna noting that the requirements and revised terminology imposed by TSTF-493 and RIS 2006-17 (Refs. 5.99 and 5.100) will be incorporated into the methodology as appropriate. Kewaunee Power Station has chosen to implement TSTF-493, Revision 4, Option B as part of the conversion to Improved Technical Specifications. As stated above in Section 2.2.6, TSTF-493, Revision 4, Option B allows for the relocation of the Allowable Values associated with LCOs 3.3.1, 3.3.2, 3.3.5, 3.3.6, and 3.3.7 from Section 3.3 of Technical Specifications to a Licensee controlled program as defined in ITS Section 5.5.16. The Licensee controlled program is defined in ITS Section 5.5.16 as the Setpoint Control Program.

The Setpoint Control Program establishes the requirements for ensuring that setpoints for automatic protective devices are initially within and remain within the Technical Specification requirements. The Setpoint Control Program will govern the process for implementing changes to instrumentation setpoints and will describe the setpoint methodology used to ensure that setpoints are established in accordance with the requirements of Methods 1 or 2 from ISA-RP67.04.02-2000 and ISA-RP67.04-Part II-1994, TSTF-493, Revision 4, Option B, and RIS 2006-17. The automatic protective devices related to variables that perform a significant safety function at Kewaunee Power Station as delineated by 10 CFR 50.36(c)(1)(ii)(A) are described in detail in Sections 4.5, 4.6, and 4.7.

3.5.1 Primary RPS and ESFAS Trips, Permissives, and Other LCOs Credited in the Kewaunee Safety Analysis A four step process is used to determine the Allowable Value (AV), Limiting Trip Setpoint (LTSP),

Nominal Trip Setpoint (NTSP), and the As Found Tolerance (AFT) for Trip Functions, Permissives, and other LCOs at Kewaunee Power Station that are credited in the Safety Analysis. This four step process is based on the requirements of Methods 1 or 2 as described in ISA-RP67.04.02-2000 (Ref 5.43) and the revised terminology described in TSTF-493, Revision 4, and RIS 2006-17. In the order of operation, the four steps are described below and they are illustrated in Figure 3.5-1

1. Determine the Minimum (decreasing trip) or Maximum (increasing trip) Limiting Trip Setpoint (LTSP). The Maximum Limiting Trip Setpoint is arrived at by subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) (also known as the Safety Analysis Limit). The Minimum Limiting Trip Setpoint is arrived at by adding the Total Loop Uncertainty (TLU) to the Analytical Limit (AL).
2. Determine the Minimum (decreasing trip) or Maximum (increasing trip) Allowable Value (AV).

This Maximum Allowable Value is arrived at by subtracting the statistical combination (i.e., Square Root of the Sum of the Squares SRRS) of the NON COT Loop Error Components (i.e., the loop error terms that are not tested or quantified during the Channel Operational Test COT) from the Analytical Limit (AL). The Minimum Allowable Value is arrived at by adding the statistical combination of the NON COT Loop Error Components to the Analytical Limit (AL).

EE-0116 Page 40 of 199 Revision 5

3. Determine the Nominal Trip Setpoint (NTSP). After the LTSP is determined in step 1, the current Nominal Trip Setpoint for the function can be evaluated for acceptability. It may be desirable to move the current Nominal Trip Setpoint in a more conservative direction to obtain additional margin to the Analytical Limit and/or to allow for the full COT error allowance between the Nominal Trip Setpoint and the As Found Tolerance (AFT). Conversely, the current Nominal Trip Setpoint may be overly conservative resulting in reduced operating margin. If there is sufficient margin to the Analytical Limit, then it may be desirable to move the existing Nominal Trip Setpoint in the non-conservative direction to obtain additional operating margin. In all cases, the NTSP must be set equal to or, preferably, conservative with respect to the LTSP.
4. Determine the As Found Tolerance (AFT). Note that the As Found Tolerance for Kewaunee is equivalent to the Allowable Values/Limiting Safety System Settings/Setting Limits used for North Anna and Surry. After the AV is determined in step 2, the As Found Tolerance can be determined based on the NTSP. The AFT for an increasing trip function is arrived at by adding the statistical combination (i.e., Square Root of the Sum of the Squares SRRS) of the COT Loop Error Components (i.e., the loop error terms that are tested or quantified during the Channel Operational Test COT) to the Nominal Trip Setpoint (NTSP). The AFT for a decreasing trip function is arrived at by subtracting the statistical combination of the COT Loop Error Components from the Nominal Trip Setpoint. In all cases, the As Found Tolerance must be set equal to or, preferably, conservative with respect to the Allowable Value.

Kewaunee's Four Step Process Analytical Limit (AL)

NON COT ERRORS TOTAL LOOP UNCERTAINTY (TLU) Allowable Value (AV)

(STEP 2)

COT ERRORS Limiting Trip Setpoint (LTSP)

(STEP 1)

As Found Tolerance (AFT)

(STEP 4)

MARGIN COT ERRORS Nominal Trip Setpoint (NTSP)

(STEP 3)

Figure 3.5-1

EE-0116 Page 41 of 199 Revision 5 3.5.2 Backup RPS and ESFAS Trips, Permissives, and Other LCOs Not Credited in the Kewaunee Safety Analysis A two step process is used to determine the As Found Tolerance for Backup RPS and ESFAS Functions at Kewaunee Power Station that are not credited in the Safety Analysis. Backup RPS/ ESFAS and other LCOs Trip Functions do not have a documented Safety Limit; therefore, Limiting Trip Setpoints and Allowable Values do not need to be calculated. In some cases for Backup Trips, a TLU (i.e., CSA Calculation) may not be available to perform the process described below. In such a case, the process is subjective and should be based on the best available information. The two step process is described below.

1. Determine the Nominal Trip Setpoint (NTSP). The current Nominal Trip Setpoint for the function should be evaluated for acceptability. It may be desirable to move the current Nominal Trip Setpoint in a more conservative direction to obtain additional margin to ensure the function will support the associated Primary Trip, if applicable. Conversely, the current Nominal Trip Setpoint may be overly conservative resulting in reduced operating margin. If there is sufficient margin with respect to the associated Primary Trip Analytical Limit (if applicable), then it may be desirable to move the existing Nominal Trip Setpoint in the non-conservative direction to obtain additional operating margin.
2. Determine the As Found Tolerance (AFT). The AFT for an increasing trip function is arrived at by adding the statistical combination (i.e., Square Root of the Sum of the Squares SRRS) of the COT Loop Error Components (i.e., the loop error terms that are tested or quantified during the Channel Operational Test COT) to the Nominal Trip Setpoint (NTSP). The AFT for a decreasing trip function is arrived at by subtracting the statistical combination of the COT Loop Error Components from the Nominal Trip Setpoint (NTSP).

EE-0116 Page 42 of 199 Revision 5 3.5.3 Calculating Limiting Trip Setpoints, Allowable Values, and As Found Tolerances for Kewaunee Power Station Kewaunees Steam Generator Water Level High - High Currently, Kewaunees Custom Technical Specifications (Ref. 5.90) does not specify a Setting Limit for the Steam Generator High-High Water Level ESFAS Trip. This function will be included in the Setpoint Control Program in accordance with ITS Table 3.3.2.1, item 5.b. Based on the requirements of ITS Section 5.5.16, this function will be evaluated based on the four step method described in Section 3.5.1 to ensure that it is bounded by the CSA Calculation of record and by the Safety Analysis assumptions documented in Technical Report NE-0994 (Ref. 5.1). The example given below will be adjusted to include the revised terminology and requirements specified in TSTF-493, Revision 4 and RIS 2006-17 to support the conversion to ITS and the implementation of the Kewaunee Setpoint Control Program.

Given Information:

Analytical Limit = 100.0 % Narrow Range Level (Ref. 5.1)

Current CTS Setting Limit = not specified Current Nominal Trip Setpoint = 66.5 % Narrow Range Level (Ref. 5.112)

Total Loop Uncertainty/Channel Statistical Allowance = (+) 3.967 to (+) 7.923 % Narrow Range Level (only the most positive value is used for the analysis) (Ref. 5.97)

Type of Trip = Increasing Trip, Normally Energized (Ref. 5.112)

Functional Group = Primary Trip, Single Parameter Protection Function (Refs. 5.1 and 5.112)

Step 1 - Determine the Limiting Trip Setpoint (LTSP)

The Limiting Trip Setpoint (LTSP) is equal to the Analytical Limit (AL) minus the Total Loop Uncertainty (TLU). Thus, the LTSP is equal to:

LTSP = 100.0 % - 7.923 %

LTSP = 92.077 % Narrow Range Level Step 2 - Determine the Allowable Value (AV)

The Allowable Value (AV) is equal to the Analytical Limit (AL) minus the NON-COT loop error components taken from the Total Loop Uncertainty (TLU) calculation. The NON-COT loop error components from Kewaunee CSA Calculation C11116 (Ref. 5.97) are detailed below:

EE-0116 Page 43 of 199 Revision 5 Systematic Error (SE) = + 0.000 % of span Process Measurement Accuracy (PMA3) = + 5.945 % of span Primary Element Accuracy (PEA) = + 0.000 % of span Sensor Calibration Accuracy + Sensor Measuring & Test Equipment (SCA+SMTE) = + 0.467 % of span Sensor Drift (SD) = + 0.280 % of span Sensor Pressure Effects (SPE) + 0.577 % of span Sensor Temperature Effects (STE) = + 1.241 % of span Sensor Power Supply Effect (SPSE) = + 0.060 % of span Module 1 Measuring and Test Equipment (M1MTE) = + 0.000 % of span Module 3 Measuring and Test Equipment (M3MTE) = + 0.200 % of span Rack Temperature Effect (RTE) = + 0.500 % of span Combining the NON-COT loop error components using the Square Root of the Sum of the Squares (SRSS) method as described in Dominion Standard STD-EEN-0304 (Ref. 5.5), we have the following NON-COT total error:

NON COTerror = SE + PMA3 + [PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 + M1MTE2 +

M3MTE2 + RTE2] 1/2 NON COTerror = 0.0 + 5.945 + [0.02 + (0.25+0.217)2 + 0.2802 + 0.5772 + 1.2412 + 0.0602 + 0.02 + 0.202

+ 0.52] 1/2 NON COTerror = 7.514 % Narrow Range Level The Allowable Value (AV) for an increasing trip based on the requirements of Methods 1 or 2 as described in ISA-RP67.04.02-2000 (Ref. 5.43) is determined by subtracting the total NON-COT error from the Analytical Limit as shown below.

AV = 100.0 % - 7.514 %

AV = 92.486 % Narrow Range Level Step 3 - Determine the Nominal Trip Setpoint (NTSP)

As determined in Step 1, the Limiting Trip Setpoint is equal to 92.077 % Narrow Range Level. The current Nominal Trip Setpoint for this function at Kewaunee is 66.5 % Narrow Range Level. The Nominal Trip Setpoint is conservative with respect to the Limiting Trip Setpoint. The nominal operating band for Steam Generator Level at 100 % power is 44.0 % Level + 5.0 % Level (Refs. 5.134 and 5.135). Subtracting the worst case normal operating level of 49.0 % from the Nominal Trip Setpoint of 66.5 % yields an operating margin of 17.5 % level. This operating margin encompasses the entire Total Loop Uncertainty and should allow for stable operation. Therefore, the current Nominal Trip Setpoint of 66.5 % Narrow Range Level will be retained.

EE-0116 Page 44 of 199 Revision 5 Step 4 - Determine the As Found Tolerance (AFT)

As determined in Step 2, the Allowable Value (AV) is equal to 92.486 % Narrow Range Level. The As Found Tolerance will be based on the COT error components taken from Calculation C11116 (Ref. 5.97) as shown below.

The As Found Tolerance is equal to the Nominal Trip Setpoint plus the COT loop error components taken from the Total Loop Uncertainty (TLU) calculation. The COT loop error components from CSA Calculation C11116 are detailed below:

Module 1 - Foxboro or NUS Loop Power Supply (M1) = + 0.00 % of span Module 3 - Foxboro or NUS Bistable Module (M3) = + 0.50 % of span Rack Drift (RD) = + 1.0 % of span Combining the COT loop error components using the Square Root of the Sum of the Squares (SRSS) method as described in Dominion Standard STD-EEN-0304 (Ref. 5.5), we have the following COT total error:

COTerror = + (M12 + M32 + RD2) 1/2 COTerror = + (0.02 + 0.52 + 1.02) 1/2 COTerror = + 1.12 % Narrow Range Level As described in Step 4 above, the As Found Tolerance (AFT) for an increasing trip is determined by adding the total COT error to the Nominal Trip Setpoint as shown below.

AFT = 66.5 % + 1.12 % = 67.62 % Narrow Range Level This As Found Tolerance of 67.62 % Narrow Range Level will be included in the Setpoint Control Program to support Kewaunees conversion to ITS, noting the Nominal Trip Setpoint is equal to 66.5 %

Narrow Range Level. The Nominal Trip Setpoint and the As Found Tolerance are both set below the Allowable Value of 92.486 % Narrow Range Level and the Limiting Trip Setpoint of 92.077 % Narrow Range Level.

As Found Tolerance (AFT) = 66.5 % Narrow Range Level + 1.12 % Narrow Range Level As Left Tolerance (ALT) = 66.5 % Narrow Range Level + 0.50 % Narrow Range Level(1)

Steps 1 through 4 as they apply for Kewaunees Steam Generator High-High Water Level Reactor Trip are illustrated below in Figure 3.5-2.

(1) ALT = COT error minus Rack Drift (RD) = + (0.02 + 0.52) 1/2 = + 0.5 % of span = + 0.5 % NR Level

EE-0116 Page 45 of 199 Revision 5 KEWAUNEE'S STEAM GENERATOR HI-HI WATER LEVEL ESFAS Analytical Limit (AL) 100.00 NR Level TOTAL LOOP NON-COT ERRORS 7.514 % NR Level 7.923 % NR Level UNCERTAINTY (TLU)

Allowable Value (AV) 92.486 % NR Level COT ERRORS 0.409 % NR Level Limiting Trip Setpoint (LTSP) 92.077 % NR Level As Found Tolerance (AFT)

SAFETY MARGIN 67.62. % NR Level COT ERRORS 1.12 % NR 25.58 % NR Level Level Nominal Trip Setpoint (NTSP) 66.50 % NR Level OPERATING MARGIN 17.50 % NR Level High Operating Limit 49.00 % NR Level Nominal Operating Setpoint 44.00 % NR Level Figure 3.5-2 In addition to the above, TSTF-493, Revision 4 and RIS 2006-17 also stipulate that the As Left Tolerance be specified as part of the Setpoint Control Program. The As Left Tolerances will be specified for Kewaunees RPS instrumentation, ESFAS instrumentation, and other instrumentation associated with LCOs 3.3.5, 3.3.6, and 3.3.7 in Sections 4.5, 4.6, and 4.7, respectively. In general, for single input parameters, the As Left Tolerance will be equal to the calibration accuracy of the module or the SRSS of calibration accuracies of the modules used to develop the trip function. For multiple input parameters, the As Left Tolerance will be developed as described in Sections 4.5, 4.6, and 4.7.

EE-0116 Page 46 of 199 Revision 5 4.0 RESULTS 4.1 Allowable Values for North Anna ITS Table 3.3.1-1 (RTS Instrumentation)

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EE-0116 Page 69 of 199 Revision 5 4.2 Allowable Values for North Anna ITS Table 3.3.2-1 (ESFAS Instrumentation)

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EE-0116 Page 95 of 199 Revision 5 4.3 Limiting Safety System Settings (LSSS) for Surry Power Station Custom Technical Specifications, Section 2.3, Limiting Safety System Settings, Protective Instrumentation and Protective Instrumentation Settings for Reactor Trip Interlocks.

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EE-0116 Page 122 of 199 Revision 5 4.4 Setting Limits for Surry Power Station Custom Technical Specifications, Table 3.7-4, Engineered Safety Features Actuation System Instrumentation Setting Limits and Table 3.7-2, Engineered Safety Features Actuation System Instrumentation Operating Conditions Information Intentionally Removed Specific to Surry Power Station Only

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EE-0116 Page 143 of 199 Revision 5 4.5 Limiting Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances for Kewaunee Reactor Protection System (RPS) Instrumentation to Support the Setpoint Control Program Note : Only the limiting As Found Tolerance value will be addressed in analysis for each Reactor Trip Function described below.

Reactor Trips 4.5.1 Power Range Neutron Flux High Setpoint Reactor Trip As Found Tolerance Value : 105 % RTP + 1.5 % RTP (Refs. 5.1, 5.90, 5.91, 5.103, and 5.104)

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 110.96 % Rated Thermal Power (RTP). Subtracting the NON COT error components from the Analytical Limit yields an Allowable Value (AV) of 111.19 % RTP. The Nominal Trip Setpoint (NTSP) of 105.0 % RTP is conservative with respect to the Limiting Trip Setpoint and the As Found Tolerance Value of < 106.5 % RTP is conservative with respect to the Allowable Value. The current Custom Technical Specification (CTS) LSSS value of < 109 % RTP will be changed to an As Found Tolerance value < 106.5 % RTP to conform to the requirements of TSTF-493, Rev. 4 and RIS 2006-17. The As Found Tolerance is based on a Nominal Trip Setpoint value of 105 % RTP. The Nominal Trip Setpoint value of 105 % RTP will allow a 1.5 % RTP margin to be used for the COT error components. The revised As Found Tolerance value of < 106.5 % RTP is conservative with respect to the calculated value of < 106.56 % RTP using the CSA rack error terms from Calculation C11705 (Ref 5.91).

The calculated As Found Tolerance value for this function is < 106.562 % RTP. The 0.062 % RTP offset will be subtracted from the calculated value to arrive at a value that can be determined on the indicator. The statistical combination of the COT and NON COT error components from CSA Calculation C11705 (Ref. 5.91) are given below. The COT and NON COT error components are used in Figure 4.5.1 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = SE + (PMA12 + PMA32 + M1MTE2 + M3MTE + RTE2) 1/2 NON COTerror = 0.333 + (1.4172 + 5.1242 + 0.1852 + 0.1932 + 0.52) 1/2 NON COTerror = + 5.679 % of span = + 6.815 % RTP COTerror = + (M12 + M32 + RD2) 1/2 COTerror = + (0.052 + 0.8332 +1.02) 1/2 COTerror = + 1.302 % of span = + 1.562 % RTP (for conservatism round to + 1.5 % RTP)

As Found Tolerance (AFT) = 105 % RTP + 1.5 % RTP As Left Tolerance (ALT) = 105 % RTP + 1.0 % RTP(1)

EE-0116 Page 144 of 199 Revision 5 See Figure 4.5.1 for specific details.

(1) As Left Tolerance = + (M12 + M32) 1/2 = + (0.052 + 0.8332)1/2 = + 0.834 % of span = + 1.001 % RTP KEWAUNEE'S POWER RANGE NEUTRON FLUX HIGH REACTOR TRIP Analytical Limit (AL) 118.00 % RTP NON-COT ERRORS 6.815 % RTP TOTAL LOOP 7.040 % RTP Allowable Value (AV)

UNCERTAINTY (TLU) 111.185 % RTP COT ERRORS 0.225 % RTP Limiting Trip Setpoint (LTSP) 110.960 % RTP As Found Tolerance (AFT)

COT ERRORS SAFETY MARGIN 106.50 % RTP 1.50 % RTP 5.960 % RTP Nominal Trip Setpoint (NTSP) 105.00 % RTP OPERATING MARGIN 3.00 % RTP High Operating Limit 102.00 % RTP Nominal Operating Setpoint 100.00 % RTP Figure 4.5.1

EE-0116 Page 145 of 199 Revision 5 4.5.2 Power Range Neutron Flux Low Setpoint Reactor Trip As Found Tolerance: 24.5 % RTP + 1.5 % RTP (Refs. 5.1, 5.90, 5.91, 5.103, and 5.104)

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 27.96 % Rated Thermal Power (RTP). Subtracting the NON COT error components from the Analytical Limit yields an Allowable Value (AV) of 28.19 % RTP. The Nominal Trip Setpoint (NTSP) of 24.5 % RTP is conservative with respect to the Limiting Trip Setpoint and the As Found Tolerance Value of < 26.062 % RTP (conservatively round to < 26.0) is conservative with respect to the Allowable Value. The current Custom Technical Specification (CTS) LSSS value of < 25 % RTP will be changed to an As Found Tolerance value of < 26 % RTP to conform to the requirements of TSTF-493, Rev. 4 and RIS 2006-17. The As Found Tolerance is based on a Nominal Trip Setpoint value of 24.5 % RTP. The Nominal Trip Setpoint value of 24.5 % RTP will allow a 1.5 % RTP margin to be used for the COT error components.

The statistical combination of the COT and NON COT error components from CSA Calculation C11705 (Ref. 5.91) are given below. The COT and NON COT error components are used in Figure 4.5.2 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = SE + (PMA12 + PMA32 + M1MTE2 + M4MTE + RTE2) 1/2 NON COTerror = 0.333 + (1.4172 + 5.1242 + 0.1852 + 0.1932 + 0.52) 1/2 NON COTerror = + 5.679 % of span = + 6.815 % RTP COTerror = + (M12 + M42 + RD2) 1/2 COTerror = + (0.052 + 0.8332 +1.02) 1/2 COTerror = + 1.302 % of span = + 1.562 % RTP (for conservatism round to + 1.5 % RTP)

As Found Tolerance (AFT) = 24.5 % RTP + 1.5 % RTP As Left Tolerance (ALT) = 24.5% RTP + 1.0 % RTP(1)

See Figure 4.5.2 for specific details.

(2) As Left Tolerance = + (M12 + M42)1/2 = + (0.052 + 0.8332)1/2 = + 0.834 % of span = + 1.001 % RTP

EE-0116 Page 146 of 199 Revision 5 KEWAUNEE'S POWER RANGE NEUTRON FLUX LOW SETPOINT REACTOR TRIP AnalyticalLimit (AL) 35.0 % RTP NON-COT ERRORS 6.815 % RTP TOTAL LOOP 7.040 % RTP UNCERTAINTY (TLU)

Allowable Value (AV) 28.19 % RTP COT ERRORS 0.225 % RTP Limiting Trip Setpoint (LTSP) 27.960 % RTP As Found Tolerance (AFT)

SAFETY MARGIN 26.00 % RTP COT ERRORS 1.5% RTP 3.46 % RTP Nominal Trip Setpoint (NTSP) 24.50 % RTP OPERATING MARGIN 13.5 % RTP High Operating Limit 11.0 % RTP Nominal Operating Setpoint 10.0 % RTP Figure 4.5.2

EE-0116 Page 147 of 199 Revision 5 4.5.3 Power Range Neutron Flux High Positive Rate Reactor Trip As Found Tolerance: 8.0 % RTP + 1.3 % RTP with a time constant of 6.0 seconds + 0.6 seconds (Refs. 5.1, 5.11, 5.73, 5.90, 5.91, and 5.104)

The current Kewaunee Custom Technical Specifications (CTS) LSSS value for this function is 15.0 % /

q / 5.0 seconds. The manner in which this specification is presented in Kewaunees CTS is different than the typical presentation in Standardized Technical Specifications (STS) or in Improved Technical Specifications (ITS). The typical expression for this function in STS or ITS would be < 15.0 % RTP with a time constant > 5.0 Seconds. For consistency and clarity, the expression for this function will be written in the ITS format. The current static Nominal Trip Setpoint (NTSP) for this function is (+) 5.0

% RTP and the Rate Lag Derivative Time Constant associated with this function is currently set at a nominal value of 2 seconds versus the required CTS LSSS value of 5.0 seconds. For Rate Lag Derivative functions, conservative settings are > the desired/required time constant. For the ITS conversion, the installed Rate Lag Derivative Time Constant value will be changed to a nominal value of 6.0 seconds in order to comply with the current CTS Technical Specification requirement. The tolerance for this dynamic function is based on the standard tolerance for dynamic functions, i.e., + 10 %

of the desired time constant (Refs. 5.11 and 5.73). With the revised Rate Lag Derivative Time Constant, the High Positive Rate Trip circuit will be more sensitive for ramp conditions. This change will require a revised static NTSP for this function to avoid spurious trips during small process perturbations. Since there is no Analytical Limit associated with this function (Ref. 5.1), the current CTS LSSS value of 15

% RTP will be used as the limiting value to determine the revised static NTSP. The setpoint methodology described in Section 3.5 (using Methods 1 or 2 from ISA-RP67.04.02-2000, Part II) shows that the COT error makes up the distance between the NTSP and the As Found Tolerance (i.e., the Allowable Value). Using this method, the revised static NTSP would be 13.7 % RTP (i.e., 15.0 % RTP

- 1.3 % RTP)(1). In this case, a significant setpoint change is required to compensate for the increased Rate Lag Derivative Time Constant, therefore the methodology used to determine the revised static NTSP will be conservatively revised to match the method used when determining Limiting Trip Setpoints (LTSPs) for Primary Trip Functions. The approximate Channel Statistical Allowance (CSA) value associated with the NIS Power Range Trips from CSA Calculation 11705 (i.e., + 7.0 % RTP) will be subtracted from the CTS LSSS value of 15.0 % RTP yielding a revised static NTSP of 8.0 % RTP.

The As Found Tolerance for this function will be 8.0 % RTP + 1.3 % RTP (i.e., the COT error). The As Found Tolerance for the Rate Lag Derivative function will be 6 seconds + 0.6 seconds.

Note : This trip function is not credited in the USAR Chapter 14 Safety Analysis (Ref. 5.1). A CSA Calculation has not been performed for this function. CSA Calculation 11705 (Ref. 5.91) and Instrument Surveillance Procedure SP-48-004A (Ref. 5.104) were used to perform this analysis.

Static As Found Tolerance (AFT) = 8.0 % RTP + 1.3 % RTP(1)

Static As Left Tolerance (ALT) = 8.0% RTP + 0.5 % RTP(2)

Dynamic As Found Tolerance = 6.0 seconds + 0.6 seconds Dynamic As Left Tolerance = 6.0 seconds + 0.6 seconds (1) AFT = + (M12+NM3112+NC3032+RD2) 1/2 = + (0.052+0.052+0.4172+1.02) 1/2 = + 1.086 % span = + 1.303 % RTP (2) ALT = + (M12+NM3112+NC3032) 1/2 = + (0.052+0.052+0.4172) 1/2 = + 0.424 % span = + 0.508 % RTP Note: the calibration accuracy of NC303 is + 0.5 % RTP = + (0.5 % / 120 %)

  • 100 % span = + 0.417 % span

EE-0116 Page 148 of 199 Revision 5 4.5.4 Power Range Neutron Flux High Negative Rate Reactor Trip As Found Tolerance: 8.0 % RTP + 1.3 % RTP with a time constant of 6.0 seconds + 0.6 seconds (Refs. 5.1, 5.11, 5.72, 5.90, 5.91, and 5.104)

The current Kewaunee Custom Technical Specifications (CTS) LSSS value for this function is 10.0 % /

q / 5.0 seconds. The manner in which this specification is presented in Kewaunees CTS is different than the typical presentation in Standardized Technical Specifications (STS) or in Improved Technical Specifications (ITS). The typical expression for this function in STS or ITS would be < 10.0 % RTP with a time constant > 5.0 Seconds. For consistency and clarity, the expression for this function will be written in the ITS format. The current static Nominal Trip Setpoint (NTSP) for this function is (-) 5.0 %

RTP and the Rate Lag Derivative Time Constant associated with this function is currently set at a nominal value of 2 seconds versus the required CTS LSSS value of 5.0 seconds. For Rate Lag Derivative functions, conservative settings are > the desired/required time constant. For the ITS conversion, the installed Rate Lag Derivative Time Constant value will be changed to a nominal value of 6.0 seconds in order to comply with the current CTS Technical Specification requirement. The tolerance for this dynamic function is based on the standard tolerance for dynamic functions, i.e., + 10 %

of the desired time constant (Refs. 5.11 and 5.73). With the revised Rate Lag Derivative Time Constant, the High Negative Rate Trip circuit will be more sensitive for ramp conditions. This change will require a revised static NTSP for this function to avoid spurious trips during small process perturbations. Since there is no Analytical Limit associated with this function (Ref. 5.1), the current CTS LSSS value of 10

% RTP will be used as the limiting value to determine the revised static NTSP. The setpoint methodology described in Section 3.5 (using Methods 1 or 2 from ISA-RP67.04.02-2000, Part II) shows that the COT error makes up the distance between the NTSP and the As Found Tolerance (or the Allowable Value). Using this method, the revised static NTSP would be 8.7 % RTP (i.e., 10.0 % RTP -

1.3 % RTP)(1). Like the High Positive Rate Trip above, a setpoint change is also required to compensate for the increased Rate Lag Derivative Time Constant. The methodology used above for the Positive Rate Trip to determine the revised static NTSP cannot be used in this case because the CTS LSSS for this function is set much closer to the NTSP. Also, it is desirable for both the Positive and Negative Rate Trips to have the same static NTSP. Therefore, an additional 0.7 % RTP will be added to the COT error so that the revised static NTSP will be 8.0 % RTP (i.e., 10 % RTP - 1.3 % RTP - 0.7 % RTP). The As Found Tolerance for this function will be 8.0 % RTP + 1.3 % RTP (i.e., the COT error). The As Found Tolerance for the Rate Lag Derivative function will be 6 seconds + 0.6 seconds.

Note : This trip function is not credited in the USAR Chapter 14 Safety Analysis (Ref. 5.1). A CSA Calculation has not been performed for this function. CSA Calculation 11705 (Ref. 5.91) and Instrument Surveillance Procedure SP-48-004A (Ref. 5.104) were used to perform this analysis.

Static As Found Tolerance (AFT) = 8.0 % RTP + 1.3 % RTP(1)

Static As Left Tolerance (ALT) = 8.0% RTP + 0.5 % RTP(2)

Dynamic As Found Tolerance = 6.0 seconds + 0.6 seconds Dynamic As Left Tolerance = 6.0 seconds + 0.6 seconds (1) AFT = + (M12+NM3112+NC3012+RD2) 1/2 = + (0.052+0.052+0.4172+1.02) 1/2 = + 1.086 % span = + 1.303 % RTP (2) ALT = + (M12+NM3112+NC3012) 1/2 = + (0.052+0.052+0.4172) 1/2 = + 0.424 % span = + 0.508 % RTP Note: the calibration accuracy of NC303 is + 0.5 % RTP = + (0.5 % / 120 %)

  • 100 % span = + 0.417 % span

EE-0116 Page 149 of 199 Revision 5 4.5.5 Intermediate Range Neutron Flux High Reactor Trip As Found Tolerance : 20.0 % RTP + 5.0 % RTP (Refs. 5.1, 5.16, 5.29, and 5.116)

The current Custom Technical Specification (CTS) LSSS value of < 40.0 % RTP is based on maintaining a Nominal Trip Setpoint value of 20.0 % RTP. The current Custom Technical Specification (CTS) LSSS value is non-conservative based on the COT error components of the Nuclear Instrumentation System. The Intermediate Range Neutron Flux High Reactor Trip function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); therefore no Channel Statistical Allowance (CSA) Calculation has been performed for this function. The typical COT error allowance for this function is approximately 5.0 % RTP. For example, the COT error for this function at Surry is equal to + 5.678 % RTP, the COT error at North Anna is + 4.403 % RTP, and the typical Standardized Technical Specifications (STS) COT allowance is 5 % RTP (Refs. 5.3, 5.16, and 5.29). The As Found Tolerance will be < 25.0 % RTP. The As Found Tolerance of < 25.0 % RTP is based on maintaining a Nominal Trip Setpoint Value of 20.0 % RTP.

Note : This trip function is not credited in the USAR Chapter 14 Safety Analysis (Ref. 5.1). A CSA Calculation has not been performed for this function. Ref. 5.116 was used in the determination of the AFT and ALT below.

As Found Tolerance (AFT) = 20.0 % RTP + 5.0 % RTP As Left Tolerance (ALT) = 20.0% RTP + 4.9 % RTP(1)

(1) ALT = + (CSA2 - RD2) 1/2 = + (5.02 - 1.22) 1/2 = + 4.854 % RTP 4.5.6 Source Range Neutron Flux High Reactor Trip As Found Tolerance: 1.0 E5 CPS + 0.54 E5 CPS, - 0.35 E5 CPS (Refs. 5.1, 5.17, 5.30, and 5.117)

The current Custom Technical Specification (CTS) LSSS for this function states within Source Range span. The current Nominal Trip Setpoint for this function is 1.0 E5 Counts Per Second (CPS). The Source Range Neutron Flux High Reactor Trip function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); therefore no Channel Statistical Allowance (CSA) Calculation has been performed for this function. The typical COT error allowance for this function is approximately + 3.0 %

of linear span. For example, the COT error for this function at Surry is equal to + 2.973 % of linear span and the COT error at North Anna is + 3.136 % of linear span (Refs. 5.17 and 5.30). To be conservative, the North Anna COT error allowance will be used in this analysis. The As Found Tolerance will be <

1.54 E5 CPS(1). The As Found Tolerance of < 1.54 E5 CPS is based on maintaining a Nominal Trip Setpoint Value of 1.0 E5 CPS.

Note : This trip function is not credited in the USAR Chapter 14 Safety Analysis (Ref. 5.1). A CSA Calculation has not been performed for this function. References 5.17, 5.30, and 5.117 were used in the determination of the AFT and ALT below.

As Found Tolerance (AFT) = 1.0 E5 CPS + 0.54 E5 CPS, - 0.35 E5 CPS(1)

As Left Tolerance (ALT) = 1.0 E5 CPS + 0.41 E5 CPS, - 0.29 E5 CPS(2)

EE-0116 Page 150 of 199 Revision 5 (1) Nominal Trip Setpoint = 1.0

  • 105 CPS log 1.0
  • 105 = 5.0 (on a 0 to 6 Decade scale)

COT error = + 3.136 % of linear span (3.136 %/100 %)

  • 6 Decades = + 0.18816 Decade High Trip Setpoint = 5.0 + 0.18816 = 5.18816 antilog 5.18816 = 1.542
  • 105 Low Trip Setpoint = 5.0 - 0.18816 = 4.81184 antilog 4.81184 = 0.648
  • 105 (2) Nominal Trip Setpoint = 1.0
  • 105 CPS log 1.0
  • 105 = 5.0 (on a 0 to 6 Decade scale)

COT error minus Rack Drift = + 2.5 % of linear span (2.5 %/100 %)

  • 6 Decades = + 0.15 Decade High Trip Setpoint = 5.0 + 0.15 = 5.15 antilog 5.15 = 1.41
  • 105 Low Trip Setpoint = 5.0 - 0.15 = 4.85 antilog 4.85 = 0.71
  • 105 4.5.7 Overtemperature T Reactor Trip As Found Tolerance: See below (Refs. 5.1, 5.90, 5.94, 5.105, 5.114, and 5.133)

The channel's maximum Trip Setpoint shall not exceed its computed Trip Setpoint by more than 2.0

% of the T span (Note that 2.0 % of the T span is equal to 3.0 % T Power)

The Overtemperature T (OTT) Reactor Trip Setpoint equation in terms of process units is:

1+t s OT TSP < T0 [ K1 - K2 * ( 1 + t s ) * (T - T') + K3 * (P - P') - f ( I)]

1 2

(Equation 4.5.7)

Where :

T0 = Indicated T at Rated Power, %

T = Average temperature, oF T = 573.0 oF P = Pressurizer pressure, psig P = 2235 psig K1 = 1.195 K2 = 0.015 / oF K3 = 0.00072 / psig I = qt - qb, where qt and qb are percent power in the top and bottom halves of the core respectively, and qt + qb is total core power in percent of rated power.

f(I) = function of I, percent of rated core power as shown in the Kewaunee COLR.

1 30.0 seconds 2 4.0 seconds The Overtemperature T (OTT) Reactor Trip Setpoint is variable and is constantly calculated based on actual plant conditions. For this reason, the Allowable Value cannot be expressed as a constant.

Further, the OTT Reactor Trip will only be analyzed for the following condition:

EE-0116 Page 151 of 199 Revision 5 The two conditions listed below are also associated with the OTT Reactor Trip. These conditions are not credited in the USAR Chapter 14 Safety Analysis and will not be analyzed here.

  • OTT Reactor Trip with (-) FI Note: FI is the Delta Flux Penalty generated from the Upper and Lower Power Range Neutron Flux Detectors (i.e., QU and QL).

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields the following Limiting Trip Setpoints (LTSP) for the OTT Reactor Trip with no FI condition as described above:

  • LTSP for OTT Reactor Trip with no FI = 130.0 % - 8.403 % = 121.597 % T Power Subtracting the NON COT error components from the Analytical Limit yields the following Allowable Value (AV) for the OTT Reactor Trip with no FI contribution as described above:
  • AV for OTT Reactor Trip with no FI = 130.0 % - 5.883 % = 124.117 % T Power For the most limiting condition (i.e., OTT Reactor Trip with no FI) the Actual Nominal Trip Setpoint of 118.25 % T Power (e.g., based on TAVG = 572.0 oF) is conservative with respect to the Limiting Trip Setpoint of 121.597 % T Power. The As Found Tolerance Value of 121.25 % T Power is conservative with respect to the Allowable Value of 124.117 % T Power. This As Found Tolerance Value of < 121.25 % T Power is based on maintaining a Nominal Trip Setpoint value of 118.25 % T Power. Note that this analysis is based on static conditions such that dynamic components are not considered.

The statistical combination of the COT and NON COT error components from CSA Calculation C11865 (Ref. 5.94) with the appropriate modifications described in Section 3.2 for the OTT Reactor Trip are given below. The COT and NON COT error components are used in Figure 4.5.7 to determine the Nominal Trip Setpoint (NTSP), Allowable Value (AV), As Found Tolerance (AFT), and As Left Tolerance (ALT) for the most limiting condition.

OTT Reactor Trip with no FI NON COTerror = SE1 + SE2 + SE3a + [PMA32 + PMA42 + PMA52 + PMA62 + PMA72 + PEA2 + (CSA3 NON 2 2 2 2 2 2 2 COT) + (CSA4 NON COT) + (CSA5 NON COT) + (CSA6 NON COT) + M7MTE + M18MTE + RTE1 +

2 2 1/2 RTE2 + RTE3 ]

Where the following terms are taken from Calculation C11865 (Ref. 5.94):

CSA3 NON COT = [(CSA1 NON COT)2 + (CSA2 NON COT)2 + (M3MTE)2 ] 1/2 CSA3 NON COT = (0.5482 + 0.5482 + 0.1732) 1/2 = 0.794 % of T span

EE-0116 Page 152 of 199 Revision 5 CSA4 NON COT = [(CSA1 NON COT

  • 0.667)2 + (CSA2 NON COT
  • 0.667)2 + (M4MTE)2 ] 1/2 CSA4 NON COT = [(0.548
  • 0.667)2 +(0.548
  • 0.667)2 + 0.2452) 1/2 = 0.572 % of T span CSA5 NON COT = (PEA2 + (SCA3 + SMTE3)2 + SD32 + SPE32 + STE32 + SPSE32 + M10MTE2)1/2 CSA5 NON COT = (0.02 + (0.096 + 0.150)2 +0.2882 + 0.02 + 0.8832 + 0.0612 + 0.02)1/2 = 0.963 % of T span CSA6a NON COT = (M15MTE2 + M16MTE2)1/2 CSA6a NON COT = (0.3462 + 0.2002)1/2 = 0.400 % of T span Thus, the total NON COTerror is equal to:

NON COTerror = 0.267 + 0.722 + 0.867 + [0.02 + 0.02 + 0.02 + 0.02 + 1.1332 + 0.02 + 0.7942 + 0.5722 +

0.9632 + 0.4002 + 0.3742 + 0.2242 + 0.52 + 0.52 + 0.52]1/2 NON COTerror = + 3.922 % of span = + 5.883 % T Power COTerror = (CSA3 COT2 + CSA4 COT2+ CSA5 COT2+ CSA6a COT2 + M72 + M182 + RD12 + RD22 + RD32)1/2 Where the following terms are taken from Calculation C11865 (Ref. 5.94):

CSA3 COT = [(CSA1 COT)2 + (CSA2 COT)2 + (M3)2 ] 1/2 CSA3 COT = (0.4172 + 0.4172 + 0.7072) 1/2 = 0.921 % of T span CSA4 COT = [(CSA1 COT

  • 0.667)2 + (CSA2 COT
  • 0.667)2 + M42] 1/2 CSA4 Cot = [(0.417
  • 0.667)2 + (0.417
  • 0.667)2 + 0.7072) 1/2 = 0.809 % of T span CSA5 COT = M10 CSA5 COT = 0.0 = 0.0 % of T span CSA6a COT = [(M15MTE)2 + (M16MTE)2]1/2 CSA6a COT = (0.5002 + 0.5002)1/2 = 0.707% of T span Thus, the COTerror is equal to:

COTerror = (0.9212 + 0.8092+ 0.02+ 0.7072 + 0.52 + 0.52 + 1.02 + 1.02 + 1.02)1/2 COTerror = + 2.346 % of T span = + 3.519 % T Power (The calculated COT error will be conservatively rounded back to + 2.0 % of T span = + 3.0 % T Power for the As Found Tolerance)

EE-0116 Page 153 of 199 Revision 5 Static As Found Tolerance (AFT) = Computed Setpoint + 3.0 % T Power Static As Left Tolerance (ALT) = Computed Setpoint + 2.4 % T Power (1)

(1) ALT = + (COTerror2 - RD12 - RD22 - RD32) 1/2 = + (2.3462 - 1.02 - 1.02 - 1.02) 1/2 ALT = + 1.582 % of T span = + 2.373 % T Power (round to + 2.4 % T Power)

KEWAUNEE'S OVERTEMPERATURE DELTA T REACTOR TRIP Analytical Limit (AL) 130.0 % Delta T Power TOTAL LOOP NON-COT ERRORS 5.883 % DT PWR 8.403 % DT Power UNCERTAINTY (TLU)

Allowable Value (AV) 2.520 % DT PWR 124.117 % Delta T Power COT ERRORS Limiting Trip Setpoint (LTSP) 121.597 % Delta T Power As Found Tolerance (AFT) 121.25 % Delta T Power COT ERRORS 3.00 % DT PWR SAFETY MARGIN 3.347 % DELTA T POWER Nominal Trip Setpoint (NTSP) 118.25 % Delta T Power OPERATING MARGIN 16.25 % DELTA T POWER High Operating Limit 102.00 % Delta T Power Nominal Operating Limit 100.00 % Delta T Power Figure 4.5.7

EE-0116 Page 154 of 199 Revision 5 4.5.8 Overpower T Reactor Trip As Found Tolerance: See below (Refs. 5.1, 5.90, 5.94, and 5.105)

" The channel's maximum Trip Setpoint shall not exceed its computed Trip Setpoint by more than 1.546 % of the T span " (Note that 1.525 % of the T span is equal to 2.288 % T Power)

The Overpower T Reactor Trip Setpoint is variable and is constantly calculated based on actual plant conditions. For this reason, the Allowable Value cannot be expressed as a constant. The Overpower T Reactor Trip is a backup reactor trip function and is not credited in the USAR Chapter 14 Safety Analysis (Ref. 5.1). The As Found Tolerance of + 1.525 % of T span = + 2.288 % T Power(1) is based on the COT error components from CSA Calculation (Ref. 5.94). The As Left Tolerance is based on the As Found Tolerance minus Rack Drift.

Static As Found Tolerance (AFT) = Computed Setpoint + 2.288 % T Power(1)

Static As Left Tolerance (ALT) = Computed Setpoint + 1.724 % T Power (2)

(1) The Overpower T Reactor Trip COT error is taken from Calculation C11865 (Ref. 5.94).

AFT = + (M12 + M22 + M32 + M42 + M52 + M62 + M172 + RD12 + RD22) 1/2 AFT = + (0.4172 + 0.4172 + 0.7072 + (0.707

  • 0.667)2 + 0.0342 + 0.0342 + 0.52 + 1.02 + (1.0
  • 0.069)2) 1/2 AFT = + 1.525 % of T span = + 2.288 % T Power (2) ALT = + (COTerror2 - RD12 - RD22) 1/2 = + (1.5252 - 1.02 - 0.0692) 1/2 ALT = + 1.149 % of T span = + 1.724 % T Power 4.5.9 Pressurizer Low Pressure Reactor Trip As Found Tolerance: 1904 PSIG + 10.0 PSIG (Refs. 5.1, 5.90, 5.93, and 5.105)

Adding the Total Loop Uncertainty (TLU) to the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 1858.82 PSIG. Adding the NON COT error components to the Analytical Limit yields an Allowable Value (AV) of 1855.94 PSIG. The Actual Nominal Trip Setpoint of 1904 PSIG is conservative with respect to the Limiting Trip Setpoint. The current Custom Technical Specification (CTS) LSSS value of > 1875 PSIG is conservative with respect to the Allowable Value. The current Custom Technical Specification (CTS) LSSS value of > 1875 PSIG is non-conservative based on the calculated COT error components determined in Calculation C10818 (Ref. 5.93). The LSSS value of >

1875 PSIG will be changed to an As Found Tolerance value of > 1894 PSIG to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17. This As Found Tolerance is based on a Nominal Trip Setpoint value of 1904.0 PSIG. The Nominal Trip Setpoint value of 1904 PSIG will allow a 10.0 PSIG margin to be used for the COT error components. The As Found Tolerance value of > 1894 PSIG is sufficiently close enough to the calculated value using the CSA rack error terms from Calculation C10818 (Ref. 5.93).

The calculated As Found Tolerance for this function is > 1894.20 PSIG. The 0.20 PSIG offset is accommodated in the 45.18 PSIG Safety Margin for this trip as illustrated in Figure 4.5.9.

EE-0116 Page 155 of 199 Revision 5 The statistical combination of the COT and NON COT error components from CSA Calculation C10818 (Ref. 5.93) are given below. The COT and NON COT error components are used in Figure 4.5.9 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = SE + [PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 + M1MTE2 +

M2MTE2 + M3MTE2 + RTE2] 1/2 NON COTerror = 0.0 + [0.02 + 0.02 + (0.250 + 0.391)2 + 0.752 + 0.02 + 2.3002 + 0.1582 + 0.02 + 0.2002 +

0.2832 + 0.52]1/2 NON COTerror = + 2.580 % of span = + 20.64 PSIG COTerror = + (M12 + M22 + M32 + RD2) 1/2 COTerror = + (0.02 + 0.52 + 0.52 + 1.02) 1/2 COTerror = + 1.225 % of span = + 9.80 PSIG (round to + 10 PSIG)

As Found Tolerance (AFT) = 1904 PSIG + 10.0 PSIG As Left Tolerance (ALT) = 1904 PSIG + 5.7 PSIG(1)

See Figure 4.5.9 for specific details.

(1) ALT = + (COTerror2 - RD2) 1/2 = + (1.2252 - 1.02) 1/2 = + 0.71 % of span = + 5.7 PSIG

EE-0116 Page 156 of 199 Revision 5 KEWAUNEE'S PRESSURIZER LOW PRESSURE REACTOR TRIP Nominal Operating Limit 2235 PSIG Low Operating Limit 2210 PSIG OPERATING MARGIN 306 PSIG (Static)

Nominal Trip Setpoint (NTSP) 1904 PSIG COT ERRORS 10.00 PSIG SAFETY MARGIN 45.18 PSIG (Static)

As Found Tolerance (AFT) 1894.00 PSIG Limiting Trip Setpoint (LTSP) 1858.82 PSIG COT 2.88 PSIG TOTAL LOOP ERRORS 23.52 PSIG Allowable Value (AV) 1855.94 PSIG UNCERTAINTY (TLU)

NON-COT ERRORS 20.64 PSIG Analytical Limit (AL) 1835.3 PSIG Figure 4.5.9

EE-0116 Page 157 of 199 Revision 5 4.5.10 Pressurizer High Pressure Reactor Trip As Found Tolerance: 2377 PSIG + 9.0 PSIG (Refs. 5.1, 5.90, 5.93, and 5.105)

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 2387.64 PSIG. Subtracting the NON COT error components from the Analytical Limit yields an Allowable Value (AV) of 2389.78 PSIG. The Actual Nominal Trip Setpoint of 2377 PSIG is conservative with respect to the Limiting Trip Setpoint. The current Custom Technical Specification (CTS) LSSS value < 2385 PSIG is conservative with respect to the Allowable Value. The CTS LSSS value < 2385 PSIG will be revised to an As Found Tolerance Value of < 2386 PSIG based on the COT error components calculated below. The revised As Found Tolerance Value of < 2386 PSIG is also conservative with respect to the Allowable Value, however it is slightly non-conservative with respect to the calculated value using the CSA rack error components from Calculation C10818 (Ref 5.93). The calculated As Found Tolerance Value for this function is < 2385.94 PSIG. The 0.06 PSIG offset from the calculated value is accommodated within the Safety Margin for this function (i.e., 10.64 PSIG). The As Found Tolerance value of < 2386 PSIG is based on the Nominal Trip Setpoint value of 2377.0 PSIG.

The statistical combination of the COT and NON COT error components from CSA Calculation C10818 (Ref. 5.93) are given below. The COT and NON COT error components are used in Figure 4.5.10 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = SE + [PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 + M1MTE2 +

M2MTE2 + RTE2] 1/2 NON COTerror = 0.0 + [0.02 + 0.02 + (0.250 + 0.391)2 + 0.752 + 0.02 + 2.3002 + 0.1582 + 0.02 + 0.2002 +

0.52]1/2 NON COTerror = + 2.565 % of span = + 20.52 PSIG COTerror = + (M12 + M22 + RD2) 1/2 COTerror = + (0.02 + 0.52 + 1.02) 1/2 COTerror = + 1.118 % of span = + 8.944 PSIG (round to + 9.0 PSIG)

As Found Tolerance (AFT) = 2377 PSIG + 9.0 PSIG As Left Tolerance (ALT) = 2377 PSIG + 4.0 PSIG(1)

See Figure 4.5.10 for specific details.

(1) ALT = + M2 = + 0.5 % of span = + 4.0 PSIG

EE-0116 Page 158 of 199 Revision 5 KEWAUNEE'S PRESSURIZER HIGH PRESSURE REACTOR TRIP Analytical Limit (AL) 2410.3 PSIG NON-COT ERRORS 20.52 PSIG TOTAL LOOP 22.66 PSIG Allowable Value (AV)

UNCERTAINTY (TLU) 2389.78 PSIG COT ERRORS 2.14 PSIG Limiting Trip Setpoint (LTSP) 2387.64 PSIG As Found Tolerance (AFT)

SAFETY MARGIN COT ERRORS 2386.00 PSIG 9.00 PSIG 10.64 PSIG Nominal Trip Setpoint (NTSP) 2377 PSIG OPERATING MARGIN 117 PSIG High Operating Limit 2260 PSIG Nominal Operating Setpoint 2235 PSIG Figure 4.5.10

EE-0116 Page 159 of 199 Revision 5 4.5.11 Reactor Coolant Flow Low Reactor Trip (Normalized)

Allowable Value: As Found Tolerance = 93% Flow + 1.1% Flow (Refs. 5.1, 5.90, 5.96, 5.106, and 5.120)

Adding the Total Loop Uncertainty (TLU) to the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 90.52 % Flow. Adding the NON COT error components to the Analytical Limit yields an Allowable Value (AV) of 90.27 % Flow. The current Nominal Trip Setpoint of 93.0 % Flow is conservative with respect to the Limiting Trip Setpoint and the current Custom Technical Specification (CTS) LSSS value of > 90.0 % Flow is non conservative with respect to the Allowable Value. The CTS LSSS value > 90.0 % Flow will be changed to an As Found Tolerance value of > 91.9 % Flow based on the calculated value using the CSA rack error terms from Calculation C10819 (Ref 5.96). The As Found Tolerance of > 91.9 % Flow is conservative and conforms to the methodology described in TSFT-493, Rev. 4 and RIS 2006-17.

The calculated As Found Tolerance Value for this function is > 91.853 % Flow. The 0.047 % Flow offset will be negated resulting in a conservative As Found Tolerance value of > 91.9 % Flow for this trip as illustrated in Figure 4.5.11.

The statistical combination of the COT and NON COT error components from CSA Calculation C10819 (Ref. 5.96) are given below. The COT and NON COT error components are used in Figure 4.5.11 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror (P span) = [(SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 +

M2MTE2]1/2 NON COTerror (P span) = [(0.250 + 0.110)2 + 0.502 + 0.02 + 0.7132 + 0.1102 + 0.2002]1/2 NON COTerror (P span) = + 0.970 % of P span = + 0.574 % of Flow span @ 93 % Flow(1)

NON COTerror (Flow span) = SE + (PMA2 + PEA2 + RTE2) 1/2 NON COTerror (Flow span) = 0.372 + (2.4552 + 0.4552 + 0.52) 1/2 NON COTerror (Flow span) = 2.918 % of Flow span TOTAL NON COTerror (Flow span) = (2.9182 + 0.5742) 1/2 = 2.974 % of Flow span = 3.271 % Flow @

93.0 % Flow (e.g., the Nominal Trip Setpoint).

COTerror (P span ) = + M2 COTerror (P span ) = + 0.50 % of P span COTerror (P span) = + 0.50 % of P span = + 0.296 % of Flow span @ 93 % Flow = + 0.326 % Flow(1)

COTerror (Flow span) = RD = + 1.0 % of Flow span = + 1.10 % Flow

EE-0116 Page 160 of 199 Revision 5 TOTAL COTerror (Flow span) = (0.2962 + 1.02) 1/2

= 1.043 % of Flow span = 1.147 % Flow @ 93.0 %

Flow (e.g., the Nominal Trip Setpoint) (1)

As Found Tolerance (AFT) = 93% Flow + 1.1% Flow(1)

As Left Tolerance (ALT) = 93% Flow + 0.55% Flow(2)

See Figure 4.5.11 for specific details.

KEWAUNEE'S REACTOR COOLANT LOW FLOW REACTOR TRIP Nominal Operating Limit 100 % Flow OPERATING MARGIN 7.0 % Flow Nominal Trip Setpoint (NTSP) 93.0 % Flow COT ERRORS 1.1 % Flow SAFETY MARGIN 2.485 % Flow As Found Tolerance (AFT) 91.9 % Flow Limiting Trip Setpoint (LTSP) 90.515 % Flow COT ERRORS 0.244 %

TOTAL LOOP Flow 3.515 % Flow Allowable Value (AV)

UNCERTAINTY (TLU) 90.271 % Flow NON-COT ERRORS 3.271 % Flow Analytical Limit (AL) 87.0 % Flow Figure 4.5.11 (1) The equation to convert % P error to % Flow error is: % flow span = (P uncertainty)

  • 0.5 * (flow max / flow x) (Ref. 5.120)

(2) The calculated As Left Tolerance is + 0.296 % of Flow Span. This tolerance is too restrictive and will be set at + 0.5 % of Flow Span (i.e., like all other Bistable tolerances). The + 0.204 % of Flow Span offset is accommodated in the Safety Margin of 2.485

% Flow = 2.259 % of Flow Span.

EE-0116 Page 161 of 199 Revision 5 4.5.12 Reactor Coolant Pump Undervoltage As Found Tolerance: 76.667 + 0.885 % of normal voltage = 92 + 1.06 VAC (Refs. 5.1, 5.90, 5.127, and 5.128)

The current Custom Technical Specification (CTS) LSSS for this function is > 75 % of normal voltage.

The current Nominal Trip Setpoint for this function is 91 to 93 VAC where 92 VAC is the centerline voltage = 76.667 % of voltage span (Ref. 5.127). This analysis assumes that 120 VAC from the potential transformer is equal to 100 % of bus voltage/normal voltage which is equal to 4160 VAC. The Reactor Coolant Pump Undervoltage Trip function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); however a Channel Statistical Allowance (CSA) Calculation has been performed for this function. The calibration accuracy for this trip function is 92 + 1.0 VAC = 76.667 + 0.833 % of normal voltage (Ref. 5.127). The COT error from Calculation C11891 is + 1.06 VAC = + 0.885 % of normal voltage. Therefore, the As Found Tolerance for the Reactor Coolant Pump Undervoltage Trip is 76.667 + 0.885 % of normal voltage = 92 + 1.06 VAC based on device calibration accuracy and drift from Reference 5.128. The As Left Tolerance for the Reactor Coolant Pump Undervoltage Trip is 76.667 + 0.833 % of normal voltage = 92 + 1.0 VAC based on the device calibration accuracy from Reference 5.127. The As Found and As Left Tolerances are based on maintaining a Nominal Trip Setpoint Value 92 VAC = 76.667 % of normal voltage.

As Found Tolerance (AFT) = 76.667 + 0.885 % of normal voltage = 92 + 1.06 VAC(1)

As Left Tolerance (ALT) = 76.667 + 0.833 % of normal voltage = 92 + 1.0 VAC(2)

(1) AFT = + (SCA2 + SD2) 1/2 = + (0.8332 + 0.3002) 1/2 = + 0.885 % of normal voltage = + 1.06 VAC (2) ALT = + SCA = + 0.833 % of normal voltage = + 1.0 VAC 4.5.13 Reactor Coolant Pump Underfrequency As Found Tolerance: 57 + 0.3 Hz (Refs. 5.1, 5.90, 5.126, and 5.127)

The current Custom Technical Specification (CTS) LSSS for this function is > 55.0 Hz. The current Nominal Trip Setpoint for this function is 57 + 0.1 Hz (Ref. 5.127). The Reactor Coolant Pump Underfrequency Trip function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref.

5.1); however a Channel Statistical Allowance (CSA) Calculation has been performed for this function.

Based on Calculation C11890 (Ref. 5.126), the COT error allowance for this function is + 0.3 Hz. The calibration accuracy for this trip function is + 0.1 Hz (Ref. 5.127). The As Found Tolerance of 57 + 0.3 Hz is based on the COT error from Calculation C11890 and the As Left Tolerance of 57 + 0.1 Hz is conservatively based on device calibration accuracy from Reference 5.127. The As Found and As Left Tolerances are based on maintaining a Nominal Trip Setpoint Value of 57 Hz.

As Found Tolerance (AFT) = 57 + 0.3 Hz(1) (3)

As Left Tolerance (ALT) = 57 + 0.1 Hz(2)

(1) AFT = + (SCA2 + SD2) 1/2 = + (6.662 + 0.6672) 1/2 = + 6.69 % of frequency span or (6.69% /100%) x 4.5 Hz(3) = + 0.3 Hz (2) ALT = Current Calibration Accuracy from Reference 5.127 = + 0.1 Hz (3) The frequency span of 4.5 Hz is taken from Calculation C11890 (Ref. 5.126).

EE-0116 Page 162 of 199 Revision 5 4.5.14 Pressurizer High Level Reactor Trip As Found Tolerance: 85.0 % Level + 1.12 % Level (Refs. 5.1, 5.90, 5.92, and 5.109)

The current Custom Technical Specification (CTS) LSSS for this function is < 90.0 % Level. The current Nominal Trip Setpoint for this function is 85.0 % Level (Ref. 5.109). The Pressurizer High Level Reactor Trip function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref.

5.1); however a Channel Statistical Allowance (CSA) Calculation has been performed for this function.

Based on Calculation C10982 (Ref. 5.92), the COT error allowance for this function is + 1.118 % of span = + 1.118 % Level. The calibration accuracy for this trip function is + 0.5 % of span = + 0.5 %

Level (Ref. 5.109). The As Found Tolerance based on the COT error from Calculation C10982 is 85 +

1.118 % Level (round to 85 + 1.12 % Level). The As Left Tolerance is 85 + 0.5 % Level is based on device calibration accuracy from Reference 5.109. The As Found and As Left Tolerances are based on maintaining a Nominal Trip Setpoint Value of 85 % Level.

As Found Tolerance (AFT) = 85.0 % Level + 1.12 % Level(1)

As Left Tolerance (ALT) = 85.0 % Level + 0.5 % Level(2)

(1) AFT = + (M22 + RD2) 1/2 = + (0.52 + 1.02) 1/2 = + 1.118 % span = + 1.118 % Level (2) ALT = + M2 = + 0.5 % span = + 0.5 % Level 4.5.15 Steam Generator Water Level Low Low Reactor Trip As Found Tolerance: 17.0 % Level + 1.12 % Level (Refs. 5.1, 5.90, 5.97, 5.112, and 5.134)

Note: The Analytical Limit for this function is 0.0 % NR Level (Ref. 5.1). The Channel Statistical Allowance (CSA) for this function has a large negative Process Measurement Accuracy (PMA) bias term which results in a negative CSA value. For conservatism, the absolute value of the larger CSA value from Reference 5.97 will be used in this analysis.

Adding the Total Loop Uncertainty (TLU) to the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 4.496 % NR Level. Adding the NON COT error components to the Analytical Limit yields an Allowable Value (AV) of 4.087 % NR Level. The Actual Nominal Trip Setpoint of 17.0 % NR Level (Ref. 5.112) is conservative with respect to the Limiting Trip Setpoint and the current Custom Technical Specification (CTS) LSSS value of > 5.0 % NR Level is conservative with respect to the Allowable Value. The CTS LSSS value of > 5.0 % NR Level is non-conservative based on the calculated COT error components determined in Calculation C11116 (Ref. 5.97). The CTS LSSS value of > 5.0 % NR Level will be changed to an As Found Tolerance value of > 15.88 % NR Level to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17. The As Found Tolerance Value of

> 15.88 % NR Level is based on maintaining a Nominal Trip Setpoint value of 17.0 % NR Level.

The statistical combination of the COT and NON COT error components from CSA Calculation C11116 (Ref. 5.97) are given below. The COT and NON COT error components are used in Figure 4.5.15 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

EE-0116 Page 163 of 199 Revision 5 NON COTerror = PMA2 + (PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE + M1MTE2 +

M3MTE2 + RTE2) 1/2 NON COTerror = 2.518 + [0.02 + (0.250+0.217)2 + 0.2802 + 0.5772 + 1.2412 + 0.0602 + 02 + 0.2002 +

0.52]1/2 NON COTerror = + 4.087 % of span = + 4.087 % NR Level (worst case).

COTerror = + (M12 + M32 + RD2) 1/2 COTerror = + (0.02 + 0.52 + 1.02) 1/2 COTerror = + 1.118 % of span = + 1.118 % NR Level (round to + 1.12 % NR Level)

As Found Tolerance (AFT) = 17.0 % Level + 1.12 % Level(1)

As Left Tolerance (ALT) = 17.0 % Level + 0.5 % Level(2)

See Figure 4.5.15 for specific details.

(1) AFT = + (M32 + RD2) 1/2 = + (0.52 + 1.02) 1/2 = + 1.118 % span = + 1.118 % Level (round to + 1.12 % NR Level)

(2) ALT = + M3 = + 0.5 % span = + 0.5 % Level

EE-0116 Page 164 of 199 Revision 5 KEWAUNEE'S STEAM GENERATOR LO-LO LEVEL REACTOR TRIP Nominal Operating Limit 44.0 % NR Level Low Operating Limit 39.0 % NR Level OPERATING MARGIN 22.0 % NR Level Nominal Trip Setpoint (NTSP) 17.0 % NR Level COT ERRORS 1.12 % NR Level SAFETY MARGIN 12.504 % NR Level As Found tolerance (AFT) 15.88 % NR Level Limiting Trip Setpoint (LTSP) 0.409 % NR Level 4.496 % NR Level COT ERRORS TOTAL LOOP 4.496 % NR Level Allowable Value (AV) 4.087 % NR Level UNCERTAINTY (TLU)

NON-COT ERRORS 4.087 % NR Level Analytical Limit (AL) 0.0 % NR Level Figure 4.5.15

EE-0116 Page 165 of 199 Revision 5 4.5.16 Steam Generator Water Level Low Coincident Reactor Trip As Found Tolerance: 25.5 % Level + 1.12 % NR Level (Refs. 5.1, 5.90, 5.97, and 5.112)

The Steam Generator Water Level Low Coincident Reactor Trip is not addressed in the current version of Kewaunees Custom Technical Specifications (CTS). This function will now be included in the Setpoint Control Program based on the requirements of ITS Table 3.3.1-1, item 15. The current Nominal Trip Setpoint for this function is 25.5 % NR Level (Ref. 5.112). The Steam Generator Water Level Low Coincident Trip function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); however a Channel Statistical Allowance (CSA) Calculation has been performed for this function. Based on Calculation C11116 (Ref. 5.97), the COT error allowance for this function is +

1.118 % of span = + 1.118 % NR Level. The calibration accuracy for this trip function is + 0.5 % of span = + 0.5 % Level (Ref. 5.112). The As Found Tolerance based on the COT error from Calculation C11116 is 25.5 + 1.118 % NR Level (round to 25.5 + 1.12 % NR Level). The As Left Tolerance is 25.5

+ 0.5 % NR Level is based on the device calibration accuracy from Reference 5.112. The As Found and As Left Tolerances are based on maintaining a Nominal Trip Setpoint Value of 25.5 % NR Level.

As Found Tolerance (AFT) = 25.5 % Level + 1.12 % NR Level(1)

As Left Tolerance (ALT) = 25.5 % Level + 0.5 % NR Level(2)

(1) AFT = + (M22 + RD2) 1/2 = + (0.52 + 1.02) 1/2 = + 1.118 % span = + 1.118 % NR Level (2) ALT = + M2 = + 0.5 % span = + 0.5 % NR Level 4.5.17 Steam Flow Feed Flow Mismatch Coincident Reactor Trip As Found Tolerance: 0.87

  • 106 PPH + 0.063
  • 106 PPH (Refs. 5.1, 5.90, 5.98, 5.108, and 5.130)

The Steam Flow Feed Flow Mismatch Coincident Reactor Trip is not addressed in the current version of Kewaunees Custom Technical Specifications (CTS). This function will now be included in the Setpoint Control Program based on the requirements of ITS Table 3.3.1-1, item 15. The current Nominal Trip Setpoint for this function is 0.87

  • 106 Pound Per Hour (PPH) (Ref. 5.108). Based on Reference 5.108, the maximum Steam and Feedwater flowrate is 4.47
  • 106 PPH and the nominal flowrate at 100 % power (i.e., Flownom) is 3.82
  • 106 PPH (Ref. 5.98). This means that the current Nominal Trip Setpoint is set at 22.77 % of Flownom. The Steam Flow Feed Flow Mismatch Coincident Reactor Trip function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1) and a Channel Statistical Allowance (CSA) Calculation has not been performed for this function. The COT error allowance for this function will be based on the applicable module calibration accuracies given in Reference 5.108 and the standard + 1.0 % of span Rack Drift (RD) value from Reference 5.5. Based on References 5.108 and 5.130, there are four modules with calibration accuracies that develop this trip function. The COT error allowance based on References 5.5 and 5.108 is + 1.414 % of Flow Span = +

0.063

  • 106 PPH (1). The As Found Tolerance based on References 5.5, 5.108, and 5.130 is 0.87
  • 106 PPH + 0.063
  • 106 PPH. The As Left Tolerance based on calibration accuracy of the four devices from Reference 5.108 is 0.87
  • 106 PPH + 0.045
  • 106 PPH. The As Found and As Left Tolerances are based on maintaining a Nominal Trip Setpoint Value of 0.87
  • 106 PPH.

EE-0116 Page 166 of 199 Revision 5 As Found Tolerance (AFT) = 0.87

  • 106 PPH + 0.063
  • 106 PPH (1)

As Left Tolerance (ALT) = 0.87

  • 106 PPH + 0.045
  • 106 PPH (2)

(1) AFT = + (FM-466A2 + FC-466B/C2 + FM-464A2 + FM-464B2 + RD2) 1/2 AFT = + (0.52 + 0.52 + 0.52 + 0.52 + 1.02) 1/2 = + 1.414 % of Flow Span = + 0.063

  • 106 PPH (round to + 0.045
  • 106 PPH) 4.5.18 Safety Injection (SI) Input from Engineered Safety Features Actuation System (ESFAS)

See Section 4.6.

EE-0116 Page 167 of 199 Revision 5 Reactor Trip Permissives Note : Only the limiting As Found Tolerance value will be addressed in analysis for each Reactor Trip Permissive described below.

4.5.19 Permissive P-6, Intermediate Range Neutron Flux As Found Tolerance: Permissive P-6 unblock should occur between 1

  • 10-5% Rated Power and 1.27
  • 10-5% Rated Power (Refs. 5.1, 5.90, and 5.116)

The current Custom Technical Specification (CTS) LSSS for this function is > 10-5% Rated Power. The current Nominal Trip Setpoint for this function is set equal to the CTS LSSS value, i.e., 1

  • 10-5% Rated Power. Permissive P-6 is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1) and a Channel Statistical Allowance (CSA) calculation has not been performed for this function. The COT error allowance for this function will be based on a portion of the calibration accuracy for the Intermediate Range Front Panel Meter at the nominal unblock trip setpoint value of 1
  • 10-5% Rated Power, i.e., 7.9
  • 10-6% Rated Power to 1.27
  • 10-5% Rated Power as specified in Reference 5.116.

Only the high end of the tolerance value will be used to develop the As Found Tolerance for this function such that the current CTS LSSS value of 10-5% Rated Power will be the low end of the tolerance. The As Found Trip for Permissive P-6 should occur between 1

  • 10-5% Rated Power and 1.27
  • 10-5% Rated Power. Since this As Found Tolerance does not include a Rack Drift value, the As Left Tolerance will be equal to the As Found Tolerance.

As Found Tolerance (AFT) = Permissive P-6 unblock should occur between 1

  • 10-5% Rated Power and 1.27
  • 10-5% Rated Power As Left Tolerance (ALT) = Permissive P-6 unblock should occur between 1
  • 10-5% Rated Power and 1.27
  • 10-5% Rated Power 4.5.20 Permissive P-7, Block Low Power Reactor Trips and Enable High Power Trips P-10 As Found Tolerance (AFT) = 11.0 % RTP + 1.2 % RTP P-13 As Found Tolerance (AFT) = 8.8 % Turbine Load + 1.25 % Turbine Load (Refs. 5.1, 5.90, 5.91, 5.104, and 5.132)

The current Custom Technical Specification (CTS) LSSS for Permissive P-7 is < 12.2 % of Rated Power for both inputs, i.e., P-10 and P-13. Permissive P-7 is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); however, a Channel Statistical Allowance (CSA) Calculation has been performed for Permissive P-10. Permissive P-7 is made up of input signals from Turbine First Stage Pressure (P-13) and NIS Power Range (P-10). Signals to the P-7 and P-10 permissives are supplied from the same bistables in the NIS Power Range drawers. P-7 and P-10 will both enable and block functions from the trip and reset points of these bistables. The calibration procedure (Ref. 5.104) for the NIS Power Range P-10 unblock input into Permissive P-7 sets the Nominal Trip Setpoint at 11.0

% RTP (increasing). The current Nominal Trip Setpoint for the Turbine First Stage Pressure input to P-7, i.e., P-13 is 8.8 % of Turbine Load (e.g., based on a nominal Turbine First Stage Pressure value of 583.5 PSIG @ 100 % Power). The COT error associated with P-10 taken from Calculation C11705 (Ref. 5.91) is + 1.085 % of span = + 1.3 % RTP (round back to + 1.2 % RTP)(1). The COT error

EE-0116 Page 168 of 199 Revision 5 associated with P-13 is + 1.12 % of span = + 1.25 % Turbine Load based on the P-13 Bistable calibration accuracy from Reference 5.132 and the standard Rack Drift (RD) error value from Reference 5.5(3). The As Found Tolerance for the P-10 input to P-7 is 11.0 + 1.2 % RTP(1). The As Left Tolerance for the P-10 input to P-7 is 11.0 + 0.5 % RTP(2). The As Found Tolerance for the P-13 input to P-7 is 8.8 + 1.25 % Turbine Load(3). The As Left Tolerance for the P-13 input to P-7 is 8.8 + 0.56 % Turbine Load(4).

P-10 As Found Tolerance (AFT) = 11.0 % RTP + 1.2 % RTP(1)

P-10 As Left Tolerance (ALT) = 11.0 % RTP + 0.5 % RTP(2)

P-13 As Found Tolerance (AFT) = 8.8 % Turbine Load + 1.25 % Turbine Load(3)

P-13 As Left Tolerance (ALT) = 8.8 % Turbine Load + 0.56 % Turbine Load(4)

(1) AFT = + (M12 + M52 + RD2) 1/2 = + (0.052 + 0.4172 + 1.02) 1/2 = + 1.085 % of span = + 1.3 % RTP. This COT error will be rounded back to + 1.2 % RTP to conform to the current CTS LSSS of < 12.2 % RTP (i.e., 11 % + 1.2 % is < 12.2 %)

(2) ALT = + (M12 + M52) 1/2 = + (0.052 + 0.4172) 1/2 = + 0.42 % of span = + 0.5 % RTP.

(3) AFT = + (PC-466A2 + RD2) 1/2 = + (0.52 + 1.02) 1/2 = + 1.12 % of span. The range of the Turbine First Stage Pressure Transmitters is 0 to 650 PSIG and the nominal 100 % Power pressure is 583.5 PSIG. (1.12 %/100 %)*650 PSIG = 7.28 PSIG. Then, (7.28 PSIG/583.5 PSIG)

  • 100 % Turbine Load = 1.25 % Turbine Load.

(4) ALT = + 0.5 % of span = (0.5 %/100 %)*650 PSIG = 3.25 PSIG. Then, (3.25 PSIG/583.5 PSIG)

  • 100 % Turbine Load =

0.56 % Turbine Load.

4.5.21 Permissive P-8, Power Range Neutron Flux As Found Tolerance (AFT) = 9.5 % RTP + 1.3 % RTP (Refs. 5.1, 5.90, 5.91, and 5.104)

The current Custom Technical Specification (CTS) LSSS for Permissive P-8 is < 10.0 % of Rated Power. The Nominal Trip Setpoint for the unblock portion of Permissive P-8 is 9.5 % RTP (Ref. 5.104).

Permissive P-8 is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1) and a Channel Statistical Allowance (CSA) Calculation has not been performed for this function. However, CSA Calculation C11705 (Ref. 5.91) has identified the COT error components associated with Permissive P-10 which uses identical circuitry to that of Permissive P-8 to generate their respective functions. The COT error associated with Permissive P-10, taken from Calculation C11705 (Ref. 5.91),

is + 1.085 % of span = + 1.3 % RTP(1). This COT error is also applicable for Permissive P-8 and will be used to develop the As Found Tolerance. Based on a Nominal Trip Setpoint of 9.5 % RTP and a COT error of + 1.3 % RTP, the As Found Tolerance for Permissive P-8 is 9.5 + 1.3 % RTP. Note that the high end of the As Found Tolerance (i.e., 9.5 % RTP + 1.3 % RTP = 10.8 % RTP) is non-conservative with respect to the current CTS LSSS of < 10 % RTP, however this As Found tolerance is acceptable because there is no specific Analytical Limit associated with this permissive. The As Left Tolerance will be equal to the COT error minus Rack Drift (RD)(2). The As Found and As Left Tolerance are based on maintaining a Nominal Trip Setpoint of 9.5 % RTP.

As Found Tolerance (AFT) = 9.5 % RTP + 1.3 % RTP(1)

As Left Tolerance (ALT) = 9.5 % RTP + 0.5 % RTP(2)

(1) AFT = + (M12 + M52 + RD2) 1/2 = + (0.052 + 0.4172 + 1.02) 1/2 = + 1.085 % of span = + 1.3 % RTP.

(2) ALT = + (M12 + M52) 1/2 = + (0.052 + 0.4172) 1/2 = + 0.42 % of span = + 0.5 % RTP.

Note: The error terms used above are from Calculation C11705 (Ref. 5.91) and they are used for Permissive P-10.

EE-0116 Page 169 of 199 Revision 5 4.5.22 Permissive P-10, Power Range Neutron Flux Unblock Low Power Reactor Trips and Block High Power Trips As Found Tolerance (AFT) = 9.0 % RTP + 1.3 % RTP (Refs. 5.1, 5.90, 5.91, and 5.104)

The current Custom Technical Specification (CTS) LSSS for Permissive P-10 (i.e., unblock the low power trips) is > 7.8 % of Rated Power. The calibration procedure (Ref. 5.104) for the NIS Power Range P-10 unblock of the low power trips sets the Nominal Trip Setpoint at 9.0 % RTP (decreasing).

Permissive P-10 is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); however, a Channel Statistical Allowance (CSA) Calculation has been performed for this function. Based on Reference 5.91, the COT error associated with P-10 is + 1.085 % of span = + 1.3 % RTP(1). This COT error will be used to develop the As Found Tolerance for this function. Based on a Nominal Trip Setpoint of 9.0 % RTP and a COT error of + 1.3 % RTP, the As Found Tolerance for Permissive P-10 is 9.0 + 1.3 % RTP. Note that the low end of the As Found Tolerance (i.e., 9.0 % RTP - 1.3 % RTP = 7.7

% RTP) is non-conservative with respect to the current CTS LSSS of > 7.8 % RTP, however this As Found tolerance is acceptable because there is no specific Analytical Limit associated with this permissive. The As Left Tolerance will be equal to the COT error minus Rack Drift (RD)(2). The As Found and As Left Tolerance are based on maintaining a Nominal Trip Setpoint of 9.0 % RTP.

As Found Tolerance (AFT) = 9.0 % RTP + 1.3 % RTP(1)

As Left Tolerance (ALT) = 9.0 % RTP + 0.5 % RTP(2)

(1) AFT = + (M12 + M52 + RD2) 1/2 = + (0.052 + 0.4172 + 1.02) 1/2 = + 1.085 % of span = + 1.3 % RTP.

(2) ALT = + (M12 + M52) 1/2 = + (0.052 + 0.4172) 1/2 = + 0.42 % of span = + 0.5 % RTP.

EE-0116 Page 170 of 199 Revision 5 4.6 Limiting Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances for Kewaunee Engineered Safety Features Actuation System (ESFAS) Instrumentation to support the Setpoint Control Program Note: Only the limiting As Found Tolerance value will be addressed in analysis for each ESFAS Trip Function described below.

4.6.1 Safety Injection, Manual Initiation As Found Tolerance: There is no specific ESFAS Trip Setpoint associated with this function.

4.6.2 High Containment Pressure - Safety Injection As Found Tolerance: As Found Tolerance = 3.6 PSIG + 0.335 PSIG (Refs. 5.1, 5.90, 5.95, 5.110, and 5.111)

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 4.237 PSIG. Subtracting the NON COT error components from the Analytical Limit yields an Allowable Value (AV) of 4.328 PSIG. The current CTS Setting Limit for this function is < 4.0 PSIG. The CTS Setting Limit for this function of < 4.0 PSIG is conservative with respect to the Allowable Value, however it is non-conservative with respect to the calculated As Found Tolerance value of 3.6 PSIG + 0.335 PSIG (i.e., 3.935 PSIG) . The Actual Nominal Trip Setpoint of 3.6 PSIG is conservative with respect to the Limiting Trip Setpoint. The CTS Setting Limit of < 4.0 PSIG will be changed to an As Found Tolerance value of 3.6 PSIG + 0.335 PSIG to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17.

The statistical combination of the COT and NON COT error components from CSA Calculation C11006 (Ref. 5.95) are given below. The COT and NON COT error components are used in Figure 4.6.2 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = [PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 + M1MTE2 +

M2MTE2 + RTE2] 1/2 NON COTerror = [0.02 + 0.02 + (0.5+0.388)2 + 0.3752 + 0.02 + 1.9502 + 0.02 + 0.02 + 0.2002 + 0.52] 1/2 NON COTerror = + 2.241 % of span = + 0.672 PSIG COTerror = + (M12 + M22 + RD2) 1/2 COTerror = + (0.02 + 0.52 + 1.02) 1/2 COTerror = + 1.118 % of span = + 0.335 PSIG As Found Tolerance (AFT) = 3.6 PSIG + 0.335 PSIG As Left Tolerance (ALT) = 3.6 PSIG + 0.15 PSIG(1)

EE-0116 Page 171 of 199 Revision 5 See Figure 4.6.2 for specific details.

(1) ALT = + M2 = + 0.5 % of span = + (0.5 % / 100 %)

  • 30 PSIG = + 0.15 PSIG KEWAUNEE'S HIGH CONTAINMENT PRESSURE (SAFETY INJECTION)

Analytical Limit (AL) 5 PSIG NON-COT ERRORS 0.672 PSIG TOTAL LOOP 0.763 PSIG UNCERTAINTY (TLU)

Allowable Value (AV) 4.328 PSIG COT ERRORS 0.091 PSIG Limiting Trip Setpoint (LTSP) 4.237 PSIG As Found Tolerance (AFT) 3.935 PSIG COT ERRORS SAFETY MARGIN 0.335 PSIG 0.637 PSIG Nominal Trip Setpoint (NTSP) 3.6 PSIG OPERATING MARGIN 1.6 PSIG High Operating Limit

< 2.0 PSIG (T.S. Section 3.6)

Nominal Operating Limit 0.0 PSIG Figure 4.6.2

EE-0116 Page 172 of 199 Revision 5 4.6.3 High - High Containment Pressure (Containment Spray)

As Found Tolerance: As Found Tolerance = 21.0 PSIG + 0.671 PSIG (Refs. 5.1, 5.90, 5.95, 5.110, and 5.111)

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 21.622 PSIG. Subtracting the NON COT error components from the Analytical Limit yields an Allowable Value (AV) of 21.827 PSIG. The current CTS Setting Limit for this function is < 23.0 PSIG. The CTS Setting Limit for this function of < 23.0 PSIG is set equal to the Analytical Limit and is non-conservative with respect to the Allowable Value. In addition, the current CTS Setting Limit is also non-conservative with respect to the calculated As Found Tolerance value of 21.0 PSIG +

0.671 PSIG (i.e., 21.671 PSIG). The Actual Nominal Trip Setpoint of 21.0 PSIG is conservative with respect to the Limiting Trip Setpoint. The CTS Setting Limit of < 23.0 PSIG will be changed to an As Found Tolerance value of 21.0 PSIG + 0.671 PSIG to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17.

The statistical combination of the COT and NON COT error components from CSA Calculation C11006 (Ref. 5.95) are given below. The COT and NON COT error components are used in Figure 4.6.3 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = (PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 + M1MTE2 +

M2MTE2 + RTE2) 1/2 NON COTerror = [0.02 + 0.02 + (0.5+0.261)2 + 0.3752 + 0.02 + 1.6772 + 0.02 + 0.02 + 0.22 + 0.52) 1/2 NON COTerror = + 1.955 % of span = + 1.173 PSIG COTerror = + (M12 + M22 + RD2) 1/2 COTerror = + (0.02 + 0.52 + 1.02) 1/2 COTerror = + 1.118 % of span = + 0.671 PSIG As Found Tolerance (AFT) = 21.0 PSIG + 0.671 PSIG As Left Tolerance (ALT) = 21.0 PSIG + 0.300 PSIG(1)

See Figure 4.6.3 for specific details.

(1) ALT = + M2 = + 0.5 % of span = + (0.5 % / 100 %)

EE-0116 Page 173 of 199 Revision 5 KEWAUNEE'S HIGH HIGH CONTAINMENT PRESSURE CONTAINMENT SPRAY INITIATION Analytical Limit (AL) 23.0 PSIG NON-COT ERRORS 1.173 PSIG TOTAL LOOP 1.378 PSIG Allowable Value (AV)

UNCERTAINTY (TLU) 21.827 PSIG COT ERRORS 0.205 PSIG As Found Tolerance (AFT) 21.671 PSIG Limiting Trip Setpoint (LTSP) 21.622 PSIG COT ERRORS 0.671 PSIG SAFETY MARGIN 0.622 PSIG Nominal Trip Setpoint (NTSP) 21.00 PSIG OPERATING MARGIN 19.0 PSIG High Operating Limit

< 2.0 PSIG Nominal Operating Limit 0.0 PSIG Figure 4.6.3

EE-0116 Page 174 of 199 Revision 5 4.6.4 High - High Containment Pressure (Steam Line Isolation)

As Found Tolerance: As Found Tolerance = 15.0 PSIG + 0.671 PSIG (Refs. 5.1, 5.90, 5.95, 5.110, and 5.111)

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 15.622 PSIG. Subtracting the NON COT error components from the Analytical Limit yields an Allowable Value (AV) of 15.827 PSIG. The current CTS Setting Limit for this function is < 17.0 PSIG. The CTS Setting Limit for this function of < 17.0 PSIG is set equal to the Analytical Limit and is non-conservative with respect to the Allowable Value. In addition, the current CTS Setting Limit is also non-conservative with respect to the calculated As Found Tolerance value of 15.0 PSIG +

0.671 PSIG (i.e., 15.671 PSIG). The Actual Nominal Trip Setpoint of 15.0 PSIG is conservative with respect to the Limiting Trip Setpoint. The CTS Setting Limit of < 17.0 PSIG will be changed to an As Found Tolerance value of 15.0 PSIG + 0.671 PSIG to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17.

The statistical combination of the COT and NON COT error components from CSA Calculation C11006 (Ref. 5.95) are given below. The COT and NON COT error components are used in Figure 4.6.4 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = (PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 + M1MTE2 +

M2MTE2 + RTE2) 1/2 NON COTerror = [0.02 + 0.02 + (0.5+0.261)2 + 0.3752 + 0.02 + 1.6772 + 0.02 + 0.02 + 0.22 + 0.52) 1/2 NON COTerror = + 1.955 % of span = + 1.173 PSIG COTerror = + (M12 + M22 + RD2) 1/2 COTerror = + (0.02 + 0.52 + 1.02) 1/2 COTerror = + 1.118 % of span = + 0.671 PSIG As Found Tolerance (AFT) = 15.0 PSIG + 0.671 PSIG As Left Tolerance (AFT) = 15.0 PSIG + 0.300 PSIG(1)

See Figure 4.6.4 for specific details.

(1) ALT = + M2 = + 0.5 % of span = + (0.5 % / 100 %)

EE-0116 Page 175 of 199 Revision 5 KEWAUNEE'S CONTAINMENT PRESSURE HI-HI STEAM LINE ISOLATION INITIATION Analytical Limit (AL) 17.0 PSIG NON-COT ERRORS 1.173 PSIG TOTAL LOOP 1.378 PSIG Allowable Value (AV)

UNCERTAINTY (TLU) 15.827 PSIG COT ERRORS 0.205 PSIG As Found Tolerance (AFT) 15.671 PSIG Limiting Trip Setpoint (LTSP) 15.622 PSIG COT ERRORS 0.671 PSIG SAFETY MARGIN 0.622 PSIG Nominal Trip Setpoint (NTSP) 15.00 PSIG OPERATING MARGIN 13.0 PSIG High Operating Limit

< 2.0 PSIG (T. S. Section 3.6)

Nominal Operating Setpoint 0.0 PSIG Figure 4.6.4

EE-0116 Page 176 of 199 Revision 5 4.6.5 Pressurizer Low Pressure (Safety Injection)

As Found Tolerance: 1830 PSIG + 10 PSIG (Refs. 5.1, 5.90, 5.93, and 5.105)

Adding the Total Loop Uncertainty (TLU) to the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 1755.62 PSIG. Adding the NON COT error components to the Analytical Limit yields an Allowable Value (AV) of 1754.94 PSIG. The Actual Nominal Trip Setpoint of 1830 PSIG is conservative with respect to the Limiting Trip Setpoint. The current Custom Technical Specification (CTS) Setting Limit value of > 1815 PSIG is conservative with respect to the Allowable Value. The current Custom Technical Specification (CTS) LSSS value > 1815 PSIG is non-conservative based on the calculated COT error components determined in Calculation C10818 (Ref. 5.93). The Setting Limit value of > 1815 PSIG will be changed to an As Found Tolerance value of 1830 PSIG + 10.0 PSIG to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17. The revised As Found Tolerance value of > 1820 PSIG will allow a 10.00 PSIG margin to be used for the COT error components. The revised As Found Tolerance value of > 1820 PSIG is conservative with respect to the calculated Allowable Value but is non-conservative with respect to the calculated As Found Tolerance value using the CSA rack error terms from Calculation C10818 (Ref. 5.93).

The calculated As Found Tolerance value for this function is > 1821.06 PSIG based on using the COT error components. The 1.06 PSIG offset is accommodated in the 74.38 PSIG Safety Margin for this trip as illustrated in Figure 4.6.5.

The statistical combination of the COT and NON COT error components from CSA Calculation C10818 (Ref. 5.93) are given below. The COT and NON COT error components are used in Figure 4.6.5 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = SE + IR + [PMA2 + PEA2 + REDBE2 + SPTE2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2

+ SPSE2 + M1MTE2 + M4MTE2 + RTE2]1/2 NON COTerror = 0.0 + 0.174 + [0.02 + 0.02 + 1.6882 + 8.02 + (0.250 + 0.391)2 + 0.752 + 0.02 + 2.3002 +

0.1582 + 0.02 + 0.22 + 0.52]1/2 NON COTerror = - 8.395 % or + 8.743 % of span = + 69.944 PSIG (worst case)

COTerror = + (M12 + M42 + RD2) 1/2 COTerror = + (0.0 + 0.52 + 1.02) 1/2 COTerror = + 1.118 % of span = + 8.944 PSIG (round to + 10 PSIG)

As Found Tolerance (AFT) = 1830 PSIG + 10 PSIG As Left Tolerance (ALT) = 1830 PSIG + 4.0 PSIG(1)

See Figure 4.6.5 for specific details.

(1) ALT = + M4 = + 0.5 % of span = + 4.0 PSIG

EE-0116 Page 177 of 199 Revision 5 KEWAUNEE'S PRESSURIZER LOW PRESSURE ESFAS INITIATION Nominal Operating Limit 2235 PSIG Low Operating Limit 2210 PSIG OPERATING MARGIN 380 PSIG Nominal Trip Setpoint (NTSP) 1830 PSIG COT ERRORS 10.0 PSIG SAFETY MARGIN As Found Tolerance (AFT) 74.38 PSIG (Static) 1820 PSIG Limiting Trip Setpoint (LTSP) 0.676 PSIG 1755.62 PSIG COT ERRORS TOTAL LOOP Allowable Value (AV) 1754.94 PSIG 70.62 PSIG NON-COT ERRORS UNCERTAINTY (TLU) 69.944 PSIG Analytical Limit (AL) 1685 PSIG Figure 4.6.5

EE-0116 Page 178 of 199 Revision 5 4.6.6 High Steam Flow Coincident with Safety Injection and Coincident with Tavg - Low Low As Found Tolerance: 0.494

  • 106 lbs/hr + 0.226
  • 106 lbs/hr (Refs. 5.1, 5.90, 5.98, 5.108, and 5.120)

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 0.944

  • 106 lbs/hr. Subtracting the NON COT error components from the Analytical Limit yields an Allowable Value (AV) of 0.981
  • 106 lbs/hr. The current CTS Setting Limit for this function is 0.745
  • 106 lbs/hr. The CTS Setting Limit for this function of 0.745
  • 106 lbs/hr is set conservative with respect to the Allowable Value; however, the current CTS Setting Limit is set non-conservative with respect to the calculated As Found Tolerance value of 0.494
  • 106 lbs/hr + 0.226
  • 106 lbs/hr (i.e., 0.720
  • 106 lbs/hr). The Actual Nominal Trip Setpoint of 0.494
  • 106 lbs/hr is conservative with respect to the Limiting Trip Setpoint. The CTS Setting Limit of 0.745
  • 106 lbs/hr will be changed to an As Found Tolerance Value of 0.494
  • 106 lbs/hr + 0.226
  • 106 lbs/hr to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17. This As Found Tolerance Value of 0.494
  • 106 lbs/hr + 0.226
  • 106 lbs/hr is based on maintaining a Nominal Trip Setpoint value of 0.494
  • 106 lbs/hr.

The statistical combination of the COT and NON COT error components from CSA Calculation C10854 (Ref. 5.98) are given below. The COT and NON COT error components are used in Figure 4.6.6 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = SE + [EA2 + PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 +

M1MTE2 + M2MTE2 + RTE2] 1/2 NON COTerror = 0.0 + [0.02 + 0.0662 + 3.3332 + (0.250+0.187)2 + 0.3862 + 0.5032 + 1.5572 + 0.1582 +

0.02 + 0.22 + 0.52]1/2 NON COTerror = + 3.801% of P span = + 17.197 % of Flow Span = + 0.769

  • 106 lbs/hr(1)

COTerror = + (M12 + M22 + RD2)1/2 COTerror = + (0.02 + 0.52 + 1.02) 1/2 COTerror = + 1.118% of P span = + 5.058 % of Flow Span = + 0.226

  • 106 lbs/hr(2)

As Found Tolerance (AFT) = 0.494

  • 106 lbs/hr + 0.226
  • 106 lbs/hr(2)

As Left Tolerance (ALT) = 0.494

  • 106 lbs/hr + 0.101
  • 106 lbs/hr(3)

See Figure 4.6.6 for specific details.

EE-0116 Page 179 of 199 Revision 5 KEWAUNEE'S HI STEAM FLOW COINCIDENT WITH SI AND LO-2 T AVG Analytical Limit (AL) 1.75

  • 106 lbs/hr TOTAL LOOP NON-COT ERRORS 0.769
  • 106 lbs/hr 0.806
  • 106 lbs/hr UNCERTAINTY (TLU)

Allowable Value (AV) 0.981

  • 106 lbs/hr COT ERRORS 0.037
  • 106 lbs/hr Limiting Trip Setpoint (LTSP) 0.944
  • 106 lbs/hr As Found Tolerance (AFT) 0.720
  • 106 lbs/hr 0.226
  • 106 lbs/hr COT ERRORS SAFETY MARGIN 0.45
  • 106 lbs/hr Nominal Trip Setpoint (NTSP) 0.494
  • 106 lbs/hr OPERATING MARGIN N/A(4)

High Operating Limit N/A(4)

Nominal Operating Limit N/A(4)

Figure 4.6.6 (1) The equation to convert % P error to % Flow error is: % flow span = (P uncertainty)

  • 0.5 * (flow max / flow x) (Ref.

5.120). According to Reference 5.98, flow max = 4.47

  • 106 lbs/hr and based on Reference 5.108, flow x = 0.494
  • 106 lbs/hr. Therefore, the NON COTerror in terms of % Flow = + 3.801
  • 0.5 * (4.47 / 0.494) = 17.197 % Flow span =

(17.197/100)

  • 4.47 = + 0.769
  • 106 lbs/hr.

(2) Using the information from Note 1 above, the AFT = COTerror in terms of % Flow = + 1.118

  • 0.5 * (4.47 / 0.494) = 5.058 %

Flow span = (5.058/100)

  • 4.47 = + 0.226
  • 106 lbs/hr.

(3) The ALT = + M2 = + 0.5 % of P span. Using the information from Note 1 above, the ALT in terms of % Flow = + 0.5

  • 0.5 * (4.47 / 0.494) = 2.262 % Flow span = (2.262/100)
  • 4.47 = + 0.101
  • 106 lbs/hr.

(4) The High Steam Flow portion of this ESFAS function is always active and will be locked in as a partial coincident trip at 0.494

  • 106 lbs/hr, i.e., at 12.9 % Power where % power = (flow x / flow nom)
  • 100 = (0.494 / 3.82)
  • 100 = 12.9. Based on Reference 5.98, flow nom (nominal steam flow at 100 % power) = 3.82
  • 106 lbs/hr.

EE-0116 Page 180 of 199 Revision 5 4.6.7 High High Steam Flow Coincident with Safety Injection As Found Tolerance: 4.3439

  • 106 lbs/hr + 0.026
  • 106 lbs/hr (Refs. 5.1, 5.90, 5.98, 5.108, and 5.120)

Subtracting the Total Loop Uncertainty (TLU) from the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 7.668

  • 106 lbs/hr. Subtracting the NON COT error components from the Analytical Limit yields an Allowable Value (AV) of 7.673
  • 106 lbs/hr. The current CTS Setting Limit for this function is 4.4
  • 106 lbs/hr. The CTS Setting Limit for this function of 4.4
  • 106 lbs/hr is set conservative with respect to the Allowable Value; however, the current CTS Setting Limit is set non-conservative with respect to the calculated As Found Tolerance value of 4.3439
  • 106 lbs/hr + 0.026
  • 106 lbs/hr (i.e., 4.3699
  • 106 lbs/hr). The Actual Nominal Trip Setpoint of 4.3439
  • 106 lbs/hr is conservative with respect to the Limiting Trip Setpoint. The CTS Setting Limit of 4.4
  • 106 lbs/hr will be changed to an As Found Tolerance Value of 4.3439
  • 106 lbs/hr + 0.026
  • 106 lbs/hr to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17. This As Found Tolerance Value of 4.3439
  • 106 lbs/hr + 0.026
  • 106 lbs/hr is based on maintaining a Nominal Trip Setpoint value of 4.3439
  • 106 lbs/hr.

The statistical combination of the COT and NON COT error components from CSA Calculation C10854 (Ref. 5.98) are given below. The COT and NON COT error components are used in Figure 4.6.7 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = SE + [EA2 + PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 +

M1MTE2 + M2MTE2 + RTE2] 1/2 NON COTerror = 0.0 + [0.02 + 0.02 + 3.3332 + (0.250+0.187)2 + 0.3862 + 0.5032 + 1.5572 + 0.1582 + 0.02

+ 0.22 + 0.52]1/2 NON COTerror = + 3.800% of P span = + 1.955 % of Flow Span = + 0.087

  • 106 lbs/hr(1)

COTerror = + (M12 + M22 + RD2)1/2 COTerror = + (0.02 + 0.52 + 1.02) 1/2 COTerror = + 1.118% of P span = + 0.575 % of Flow Span = + 0.026

  • 106 lbs/hr(2)

As Found Tolerance (AFT) = 4.3439

  • 106 lbs/hr + 0.026
  • 106 lbs/hr(2)

As Left Tolerance (ALT) = 4.3439

  • 106 lbs/hr + 0.011
  • 106 lbs/hr(3)

See Figure 4.6.7 for specific details.

EE-0116 Page 181 of 199 Revision 5 KEWAUNEE'S HI HI STEAM FLOW COINCIDENT WITH SAFETY INJECTION Analytical Limit (AL) 7.76

  • 106 lbs/hr TOTAL LOOP NON-COT ERRORS 0.087
  • 106 lbs/hr 0.092
  • 106 lbs/hr UNCERTAINTY (TLU)

Allowable Value (AV) 7.673

  • 106 lbs/hr COT ERRORS 0.005
  • 106 lbs/hr Limiting Trip Setpoint (LTSP) 7.668
  • 106 lbs/hr As Found Tolerance (AFT) 4.3699
  • 106 lbs/hr 0.026
  • 106 lbs/hr COT ERRORS SAFETY MARGIN 3.324
  • 106 lbs/hr Nominal Trip Setpoint (NTSP) 4.3439
  • 106 lbs/hr OPERATING MARGIN 0.448
  • 106 lbs/hr High Operating Limit 3.896
  • 106 lbs/hr (approx. 102 % Power)

Nominal Operating Limit 3.82

  • 106 lbs/hr (flow nom)

Figure 4.6.7 (1) The equation to convert % P error to % Flow error is: % flow span = (P uncertainty)

  • 0.5 * (flow max / flow x) (Ref.

5.120). According to Reference 5.98, flow max = 4.47

  • 106 lbs/hr and based on Reference 5.108, flow x = 4.3439
  • 106 lbs/hr. Therefore, the NON COTerror in terms of % Flow = + 3.800
  • 0.5 * (4.47 / 4.3439) = 1.955 % Flow span =

(1.955/100)

  • 4.47 = + 0.087
  • 106 lbs/hr.

(2) Using the information from Note 1 above, the AFT = COTerror in terms of % Flow = + 1.118

  • 0.5 * (4.47 / 4.3439) = 0.575

% Flow span = (0.575/100)

  • 4.47 = + 0.026
  • 106 lbs/hr.

(3) The ALT = + M2 = + 0.5 % of P span. Using the information from Note 1 above, the ALT in terms of % Flow = + 0.5

  • 0.5 * (4.47 / 4.3439) = 0.257 % Flow span = (0.257/100)
  • 4.47 = + 0.011
  • 106 lbs/hr.

EE-0116 Page 182 of 199 Revision 5 4.6.8 Low-Low TAVG Coincidence input to Steam Line Isolation As Found Tolerance Value: 541.0 oF + 1.38 oF (Refs. 5.1, 5.90, 5.94, and 5.105)

The current Custom Technical Specification (CTS) Setting Limit for this function is > 540.0 oF. The current Nominal Trip Setpoint for this function is > 541.0 oF (Ref. 5.105). The Low TAVG Coincidence input to the Steam Line Isolation ESFAS function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); however a Channel Statistical Allowance (CSA) Calculation has been performed for this function. Based on Calculation C11865 (Ref. 5.94), the COT error allowance for this function is + 1.38 % of span = + 1.38 oF. The As Found Tolerance based on the COT error from Calculation C11865 is 541 oF + 1.38 oF. The CTS Setting Limit for this function of > 540.0 oF is set slightly conservative with respect to the calculated As Found Tolerance value of 541 oF + 1.38 oF (i.e.

539.62 oF). The As Found Tolerance being slightly non-conservative with respect to the current CTS Setting Limit is acceptable because there is no Analytical Limit associated with this function. The As Left Tolerance will be based on the COT error allowance minus Rack Drift (i.e., RD2 from Ref. 5.94).

The As Found and As Left Tolerances are based on maintaining a Nominal Trip Setpoint Value of 541 o

F.

As Found Tolerance (AFT) = 541.0 oF + 1.38 oF(1)

As Left Tolerance (ALT) = 541 oF + 0.95 oF (2)

(1) AFT = + ((M1

  • 0.667)2 + (M2
  • 0.667)2 + M42 + M82 + RD22) 1/2 = +((0.417
  • 0.667)2 + (0.417
  • 0.667)2 + 0.7072 + 0.52 +

1.02) 1/2 = + 1.38 % of TAVG span (2) (2) ALT = + ((M1

  • 0.667)2 + (M2
  • 0.667)2 + M42 + M82) 1/2 = + ((0.417
  • 0.667)2 + (0.417
  • 0.667)2 + 0.7072 + 0.52) 1/2 =

+ 0.95 % of TAVG span (3) The effective gain of the TAVG summing junction is set by the relationship of the TAVG span versus the span of THOT and TCOLD (i.e., 520 to 620 oF versus 500 to 650 oF, span equal to 150 oF). For Kewaunee, the effective gain is 0.6667 V/V, therefore

% TAVG span is equal to % THOT span or TCOLD span

  • 0.6667.

4.6.9 Steam Line Pressure - Low As Found Tolerance: 514.0 PSIG + 17.15 PSIG (Refs. 5.1, 5.90, 5.98, and 5.108)

Adding the Total Loop Uncertainty (TLU) to the Analytical Limit (AL) yields a Limiting Trip Setpoint (LTSP) of 511.066 PSIG. Adding the NON COT error components to the Analytical Limit yields an Allowable Value (AV) of 504.01 PSIG. The Actual Nominal Trip Setpoint of 514.0 PSIG is conservative with respect to the Limiting Trip Setpoint. The current Custom Technical Specifications (CTS) Setting Limit of > 500 PSIG is non-conservative with respect to the calculated Allowable Value and is conservative with respect to the calculated As Found Tolerance. The As Found Tolerance of 514 PSIG + 17.15 PSIG is based on the calculated COT error allowance from Calculation C10854 (Ref.

5.98). The Custom Technical Specifications (CTS) Setting Limit of > 500 PSIG will be changed to an As Found Tolerance of 514 PSIG + 17.15 PSIG to conform to the requirements of TSFT-493, Rev. 4 and RIS 2006-17. The calculated As Left Tolerance will be based on the COT error allowance from Calculation C10854 minus Rack Drift (RD). The As Found and As Left Tolerances are based on maintaining a Nominal Trip Setpoint of 514.0 PSIG.

EE-0116 Page 183 of 199 Revision 5 The statistical combination of the COT and NON COT error components from CSA Calculation C10854 (Ref. 5.98) are given below. The COT and NON COT error components are used in Figure 4.6.9 to determine the Limiting Trip Setpoint (LTSP) and the Allowable Value (AV).

NON COTerror = SE + [EA2 + PMA2 + PEA2 + (SCA+SMTE)2 + SD2 + SPE2 + STE2 + SPSE2 +

M1MTE2 + M2MTE2 + M3MTE2 + RTE2]1/2 NON COTerror = 0.0 + [0.02 + 0.02 + 0.02 + (0.250 + 0.180)2 + 0.4292 + 0.02 + 1.4752 + 0.1582 + 0.02 +

0.2832 + 0.22 + 0.52 ]1/2 NON COTerror = + 1.715 % of span = + 24.01 PSIG COTerror = + (M12 +M22 + M32 + RD2) 1/2 COTerror = + (0.02 + 0.52 + 0.52 + 1.02) 1/2 COTerror = + 1.225 % of span = + 17.15 PSIG As Found Tolerance (AFT) = 514.0 PSIG + 17.15 PSIG As Left Tolerance (ALT) = 514 PSIG + 10.0 PSIG(1)

See Figure 4.6.9 for specific details.

(1) ALT = (M12 +M22 + M32 ) 1/2 = + (0.02 + 0.52 + 0.52) 1/2 = + 0.707 % of span = + 9.898 PSIG (round to + 10. PSIG)

EE-0116 Page 184 of 199 Revision 5 KEWAUNEE'S STEAM LINE PRESSURE LOW ESFAS INITIATION Nominal Operating Limit 790.0 PSIG Low Operating Limit 600.0 PSIG (Low Press Alarm STPT)

OPERATING MARGIN 86 PSIG (Static)

Nominal Trip Setpoint (NTSP) 514.0 PSIG COT ERRORS 17.15 PSIG SAFETY MARGIN 2.934 PSIG (Static)

As Found Tolerance (AFT) 496.85 PSIG Limiting Trip Setpoint (LTSP) 511.066 PSIG COT ERRORS 7.056 PSIG TOTAL LOOP 31.066 PSIG Allowable Value (AV) 504.01 PSIG UNCERTAINTY (TLU)

NON-COT ERRORS 24.01 PSIG Analytical Limit (AL) 480.0 PSIG Figure 4.6.9

EE-0116 Page 185 of 199 Revision 5 4.6.10 Steam Generator Water Level Low Low Reactor Trip/SI See item 4.5.15.

4.6.11 SG Water Level - High High See Section 3.5.3.

EE-0116 Page 186 of 199 Revision 5 4.7 Limiting Trip Setpoints, Allowable Values, As Found Tolerances, and As Left Tolerances for Kewaunee Instrumentation associated with LCOs 3.3.5, 3.3.6, and 3.3.7 to support the Setpoint Control Program 4.7.1 Safeguards Bus Undervoltage (Loss of Voltage)

As Found Tolerance: 84.47 + 0.200 % of Bus Voltage = 101.69 + 0.241 VAC with a time delay of 1.75 seconds + 0.25 seconds (Refs. 5.1, 5.90, 5.102, & 5.129)

The current Custom Technical Specification (CTS) Setting Limit for this function is 85 % + 2 % of bus voltage in < 2.5 secs. The current Nominal Trip Setpoint for this function is 101.49 to 101.89 VAC where 101.69 VAC is the centerline voltage = 84.47 % of bus voltage(1) (Ref. 5.102 & 5.129). This analysis assumes that 120.39 VAC from the potential transformer is equal to 100 % of bus voltage which is equal to 4160 VAC per the conversion factor as noted in footnote 1. The Safeguards Bus Undervoltage Loss of Power Trip is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); however a Channel Statistical Allowance (CSA) calculation has been performed for this function. The calibration accuracy for this trip is 101.69 + 0.2 VAC = 84.47 + 0.166 % of bus voltage (1)

(Ref. 5.129). The COT error from Calculation C11709 is + 0.200 % of bus voltage = + 0.241 VAC.

Therefore, the As Found Tolerance for the Safeguards Bus Undervoltage Loss of Power Trip is 84.47 +

0.200 % of bus voltage = 101.69 + 0.241 VAC(1) based on the device calibration accuracy from Reference 5.102. The As Left Tolerance for the Safeguards Bus Undervoltage Loss of Power Trip is 84.47 + 0.166 % of bus voltage = 101.69 + 0.200 VAC based on the device calibration accuracy from Reference 5.129. The As Found Tolerance and As Left Tolerance are based on maintaining a Nominal Trip Setpoint Value of 101.69 VAC = 84.47 % of bus voltage.

The time delay associated with this trip is based on a setpoint of 1.75 seconds + 0.01 seconds (Ref.

5.129). Calculation C11709 (Ref. 5.102) gives a total error associated with the relays as 14.14 % of the settings. Utilizing the total error of 14.14 % of the setting provides a range of 1.50 seconds to 2.00 seconds based on a setpoint of 1.75 seconds. Therefore, the Time Delay As Found Tolerance is 1.75 seconds + 0.25 seconds. The Time Delay As Left Tolerance is 1.75 + 0.10(5) second based on the device calibration accuracy from Reference 5.129.

As Found Tolerance (AFT) = 84.47 + 0.200 % of bus voltage = 101.69 + 0.241 VAC(2)

As Left Tolerance (ALT) = 84.47 + 0.166 % of bus voltage = 101.69 + 0.200 VAC(3)

Time Delay As Found Tolerance = 1.75 Seconds + 0.25 seconds Time Delay As Left Tolerance = 1.75 Seconds + 0.10 seconds(5)

As Found Tolerance (AFT) = 84.15 + 0.200 % of bus voltage = 101.31 + 0.241 VAC(4)

As Left Tolerance (ALT) = 84.15 + 0.166 % of bus voltage = 101.31 + 0.200 VAC(4)

(1) Convert % bus Voltage to VAC as follows:

4160*(% bus Volts / 100) / (sqrt (3)

  • 20
  • 0.9975) = VAC Where 20 is the PT turn down ratio and 0.9775 is the Ratio Correction Factor (Ref. 5.102).

(2) AFT = + SCA = + 0.200 % bus voltage (From Reference 5.102).

(3) ALT = Current Calibration Accuracy from Reference 5.129 = + 0.166 % bus voltage.

(4) Calculation C11709 (Ref. 5.102) recommends a setpoint change for the Safeguards Bus Undervoltage Loss of Voltage Trip. The recommended setpoint will be 101.31 + 0.200 VAC = 84.15 + 0.166 % of bus voltage for the relay Dropout.

EE-0116 Page 187 of 199 Revision 5 The COT error from Calculation C11709 is + 0.200 % of bus voltage = + 0.241 VAC. Therefore, the As Found Tolerance for the Safeguards Bus Undervoltage Loss of Power Trip is 84.15 + 0.200 % of bus voltage = 101.31 + 0.241 VAC based on the device calibration accuracy from Reference 5.102. The As Left Tolerance for the Safeguards Bus Undervoltage Loss of Power Trip is 84.15 + 0.166 % of bus voltage = 101.31 + 0.200 VAC based on the recommendation from Reference 5.102. The As Found Tolerance and As Left Tolerance are based on implementing the recommendations of Calculation C11709 and setting the Nominal Trip Setpoint to a value of 101.31 VAC = 84.15 % of bus voltage. The same Time Delay Tolerances apply for the new setpoints.

(5) Undervoltage relays 27A/B5, 27C/B5, 26A/B6, 27C/B6 have an As Left time delay of 0.01 seconds listed in the Electrical Preventive Maintenance Procedures with an As Found time delay of 0.1 seconds. The procedure value of 0.01 seconds is conservative to the As Left Tolerance of 0.1 seconds as described above.

4.7.2 Safeguards Bus Second Level Undervoltage (Degraded Voltage)

As Found Tolerance: 93.80 + 0.179 % of bus voltage = 112.93 + 0.215 VAC with a time delay of 6.72 seconds + 0.68 seconds (Refs. 5.1, 5.90, 5.102, & 5.129)

The current Custom Technical Specification (CTS) Setting Limit for this function is 93.6 % + 0.9 % of bus voltage in < 7.4 secs. The current Nominal Trip Setpoint for this function is 112.73 to 113.13 VAC where 112.93 VAC is the centerline voltage = 93.80 % of bus voltage(1) (Ref. 5.102 & 5.129). This analysis assumes that 120.39 VAC from the potential transformer is equal to 100 % of bus voltage which is equal to 4160 VAC per the conversion factor as noted in footnote 1. The Safeguards Bus Second Level Undervoltage Degraded Voltage Trip is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1); however a Channel Statistical Allowance (CSA) calculation has been performed for this function. The calibration accuracy for this trip is 112.93 + 0.2 VAC = 93.80 + 0.166

% of bus voltage (1) (Ref. 5.129). The COT error from Calculation C11709 is + 0.179 % of bus voltage =

+ 0.215 VAC. Therefore, the As Found Tolerance for the Safeguards Bus Second Level Undervoltage Degraded Voltage Trip is 93.80 + 0.179 % of bus voltage = 112.93 + 0.215 VAC based on the device calibration accuracy from Reference 5.102. The As Left Tolerance for the Safeguards Bus Second Level Undervoltage Degraded Voltage Trip is 93.80 + 0.166 % of bus voltage = 112.93 + 0.200 VAC based on the device calibration accuracy from Reference 5.129. The As Found Tolerance and As Left Tolerance are based on maintaining a Nominal Trip Setpoint Value of 112.93 VAC = 93.80 % of bus voltage.

The time delay associated with this trip is based on a setpoint of 6.72 seconds + 0.01 seconds (Ref.

5.129). Calculation C11709 (Ref. 5.102) gives a total error associated with the relays as 10.1 % of the settings. Utilizing the total error of 10.1 % of the setting provides a range of 6.04 seconds to 7.40 seconds based on a setpoint of 6.72 seconds. Therefore, the Time Delay As Found Tolerance is 6.72 seconds + 0.68 seconds. The Time Delay As Left Tolerance is 6.72 + 0.10(5) second based on the device calibration accuracy from Reference 5.129.

As Found Tolerance (AFT) = 93.80 + 0.179 % of bus voltage = 112.93 + 0.215 VAC(2)

As Left Tolerance (ALT) = 93.80 + 0.166 % of bus voltage = 112.93 + 0.200 VAC (3)

Time Delay As Found Tolerance = 6.72 Seconds + 0.68 seconds Time Delay As Left Tolerance = 6.72 Seconds + 0.10 seconds(5)

As Found Tolerance (AFT) = 93.50 + 0.200 % of bus voltage = 112.57 + 0.215 VAC(4)

As Left Tolerance (ALT) = 93.50 + 0.166 % of bus voltage = 112.57 + 0.200 VAC(4)

EE-0116 Page 188 of 199 Revision 5 (1) Convert % bus Voltage to VAC as follows:

4160*(% bus Volts / 100) / (sqrt (3)

  • 20
  • 0.9975) = VAC Where 20 is the PT turn down ratio and 0.9775 is the Ratio Correction Factor (Ref. 5.102).

(2) AFT = + SCA = + 0.179 % bus voltage (From Reference 5.102).

(3) ALT = Current Calibration Accuracy from Reference 5.129 = + 0.166 % bus voltage.

(4) Calculation C11709 (Ref. 5.102) recommends a setpoint change for the Safeguards Bus Undervoltage Degraded Voltage Trip. The recommended setpoint will be 112.57 + 0.200 VAC = 93.50 + 0.166 % of bus voltage for the relay Dropout.

The COT error from Calculation C11709 is + 0.179 % of bus voltage = + 0.215 VAC. Therefore, the As Found Tolerance for the Safeguards Bus Undervoltage Degraded Voltage Trip is 93.50 + 0.179 % of bus voltage = 112.57 +

0.215 VAC based on the device calibration accuracy from Reference 5.102. The As Left Tolerance for the Safeguards Bus Undervoltage Degraded Voltage Trip is 93.50 + 0.166 % of bus voltage = 112.57 + 0.200 VAC based on the recommendation from Reference 5.102. The As Found Tolerance and As Left Tolerance are based on implementing the recommendations of Calculation C11709 and setting the Nominal Trip Setpoint to a value of 112.57 VAC = 93.50 % of bus voltage. The same Time Delay Tolerances apply for the new setpoints.

(5) Undervoltage (Degraded Voltage) relays 27AY/B5, 27CY/B5, 26AY/B6, 27CY/B6 have an As Left time delay of 0.01 seconds listed in the Electrical Preventive Maintenance Procedures with an As Found time delay of 0.1 seconds. The procedure value of 0.01 seconds is conservative to the As Left Tolerance of 0.1 seconds as described above.

4.7.3 Forebay Level As Found Tolerance: 162 H2O + 9 H2O (Refs. 5.1, 5.90, 5.101 & 5.121)

The current Custom Technical Specifications (CTS) do not list a Setting Limit value associated with the Forebay Level Trip. The Forebay Level Trip function is not credited in the Kewaunee USAR Chapter 14 Safety Analysis (Ref. 5.1). The current As Found Nominal Trip Setpoint for this function is 162 Inches H2O Decreasing + 9.0 Inches H2O per Reference 5.121. The current As Left Nominal Trip Setpoint is 162 Inches H2O Decreasing + 4.5 Inches H2O per Reference 5.121. Per Calculation C11220 (Ref.

5.101) testing concluded that at a water level of 565 3, acceptable conditions exist for continued operation of the SW pumps. The setpoint of 162 H2O is equivalent to 566 Forebay water level per Reference 5.101, which yields a difference of 9 H2O to be used for the As Found Tolerance.

As Found Tolerance (AFT) = 162 H2O + 9 H2O(1)

As Left Tolerance (ALT) = 162 H2O + 4.5 H2O(2)

(1) AFT = Margin from minimum level for SW Pump operation - Existing Setpoint Equivalent (Ref. 5.101) = 566 - 5653

= 9 (2) ALT = Current As Left Calibration Accuracy from Reference 5.121 = 4.5

EE-0116 Page 189 of 199 Revision 5 4.7.4 Containment Purge and Vent System Radiation Particulate Detector and Radioactive Gas Detector Containment Ventilation Isolation Containment Gas & Iodine Radiation Monitors (R12)

As Found Tolerance: 2.2 E+05 CPM + BKG (Refs. 5.1, 5.90, 5.113, 5.114, 5.115, 5.123, 5.124, & 5.131)

The current Custom Technical Specifications (CTS) Setting Limit for this function states < radiation levels in exhaust duct as defined in footnote(3). The current Nominal Trip Setpoint (4) for the Containment Gas Radiation Monitor is 8.00 E +04 CPM for the High Alarm Setpoint per Reference 5.123. The Containment Gas Radiation monitor is not credited in the Chapter 14 Safety Analysis (Ref.

5.1). The Alert and Alarm setpoints are determined IAW the methodology outlined in the Kewaunee Power Station Offsite Dose Calculation Manual (ODCM) and documented in Calculation C10690 (Ref.

5.115). The High Alarm Setpoint provides the Containment Isolation signal. The calculated High Alarm Setpoint per the ODCM and Calculation C10690 (Refs. 5.113 & 5.115) is currently 2.2 E +05 CPM +

Background (BKG). The Setpoints listed in Reference 5.123 are set conservative to the values determined in the ODCM and Calculation C10690 (Refs. 5.113 & 5.115). There are currently no Analytical Limits or Allowable Values associated with this function (Ref. 5.1). The determination of the setpoints is not within the scope of the Setpoint Control Program and the current High Alarm Nominal Trip Setting of 8.00E +04 CPM is conservative with respect to the calculated value listed in the ODCM and Calculation C10690. Based on Reference 5.113 & 5.115 the As Found Tolerance will be 2.2 E +05 CPM + Background. The As Left Tolerance will be based on the existing High Alarm Setpoint listed in Reference 5.123.

As Found Tolerance (AFT) = 2.2 E+05 CPM + BKG (1)

As Left Tolerance (ALT) = 8.00 E+04 CPM (2)

(1) AFT = Setpoint taken from Reference 5.113 & 5.115 (2) ALT = Calibration Procedure Setpoint = 8.0 E+04 CPM ( Reference 5.123 & 5.124)

(3) Footnote three from Technical Specification Table 3.5-1 page 2 of 2 states The setting limits for max radiation levels are derived from ODCM Specification 3.4.1 and Table 2.2, and USAR Section 6.5.

(4) The Alert Setpoint is determined IAW References 5.113 and 5.115 and is set at 2.00 E +04 CPM per Reference 5.123.

The Alert Setpoint provides an alarm function only and the Containment Isolation signal is provided by the High Alarm Setpoint.

Containment Particulate Radiation Monitor (R11)

As Found Tolerance: 8.00 E+04 CPM (Refs. 5.1, 5.90, 5.113, 5.114, 5.115, 5.122, 5.124, & 5.131)

The current Custom Technical Specifications (CTS) Setting Limit for this function states < radiation levels in exhaust duct as defined in footnote(3). The current Nominal Trip Setpoint for the Containment Particulate Radiation Monitor is 5.00 E +04 CPM for the alert setpoint and 8.00 E +04 CPM for the High Alarm per Reference 5.122. The Containment Particulate Radiation monitor is not credited in the Chapter 14 Safety Analysis (Ref. 5.1). Per USAR Table 11.2.7 the Setpoint is set Statistically significant level above background. The Design Change Process which is controlled by the 50.59/72.48

EE-0116 Page 190 of 199 Revision 5 process is utilized to determine any setpoint changes associated with the Containment Particulate Radiation Monitors. The existing setpoints are shown on drawing E-2021 (Ref. 5.124) and were derived utilizing this process and will be maintained as the As Found Tolerance and the As Left Tolerance.

As Found Tolerance (AFT) = 8.00 E+04 CPM (1)

As Left Tolerance (ALT) = 8.00 E+04 CPM (2)

(1) AFT = Calibration Procedure Setpoint = 8.0 E+04 CPM ( Reference 5.122, & 5.124)

(2) ALT = Calibration Procedure Setpoint = 8.0 E+04 CPM ( Reference 5.122 & 5.124)

(3) Footnote three from Technical Specification Table 3.5-1 page 2 of 2 states The setting limits for max radiation levels are derived from ODCM Specification 3.4.1 and Table 2.2, and USAR Section 6.5.

4.7.5 Control Room Ventilation Radiation Monitor (R23)

As Found Tolerance: 1.00 E+04 CPM (Refs. 5.1, 5.114, 5.124, & 5.125)

The current Custom Technical Specifications (CTS) Setting Limit does not specify a Setting Limit for this Radiation Monitor. The Improved Technical Specifications have added this monitor. The current Nominal Trip Setpoint for the Control Room Ventilation Radiation Monitor is 5.00 E +03 CPM for the alert setpoint and 1.00 E +04 CPM for the High Alarm per References 5.124 and 5.125. The Control Room Ventilation Radiation Monitor is not credited in the Chapter 14 Safety Analysis (Ref. 5.1). Per USAR Table 11.2.7 the Setpoint is set Statistically significant level above background. The Design Change Process which is controlled by the 50.59/72.48 process is utilized to determine any setpoint changes associated with the Control Room Radiation Monitor. The existing setpoints are shown in drawing E-2021 (Ref. 5.124) and were derived utilizing this process and will be maintained as the As Found Tolerance and the As Left Tolerance.

As Found Tolerance (AFT) = 1.00 E+04 CPM (1)

As Left Tolerance (ALT) = 1.00 E+04 CPM (2)

(1) AFT = Calibration Procedure Setpoint = 1.0 E+04 CPM ( Reference 5.124, & 5.125)

(2) ALT = Calibration Procedure Setpoint = 1.0 E+04 CPM ( Reference 5.124, & 5.125)

EE-0116 Page 191 of 199 Revision 5

5.0 REFERENCES

5.1 Technical Report NE-0994, Revision 17, Safety Analysis Limits for Technical Specification Instrumentation - Companion to EE-0101, September 2009.

5.2 Technical Report EE-0101, Revision 10, Setpoint Basis Document - Analytical Limits, Setpoints and Calculations for Technical Specification Instrumentation At North Anna and Surry Power Stations, Dated 12-11-07.

5.3 Westinghouse - NAPS Reactor Protection System/Engineered Safety Features Actuation System Setpoint Methodology (NRC Letter - S/N 541, Dated 09-28-78).

5.4 Engineering Transmittal CEE 99-0028, Revision 0, Response to Open Items ITS LCO 3.3.1, Surry Power Station Units 1 and 2, Dated 10-29-99.

5.5 Dominion Virginia Power STD-EEN-0304, Revision 6, Calculating Instrumentation Uncertainties By the Square Root of the Sum of the Squares Method.

5.6 Dominion Virginia Power STD-GN-0030, Revision 8, Nuclear Plant Setpoints.

5.7 Surry Power Station Technical Specifications.

5.8 North Anna Power Station Technical Specifications.

5.9 USNRC Regulatory Guide 1.105, Revision 3 (December 1999), Setpoints for Safety-Related Instrumentation.

5.10 Improved Thermal Design Procedure, Instrument Uncertainties for North Anna Units 1 & 2 Core Uprating C. R. Tuley July 1986, Westinghouse Electric Corporation.

5.11 Dominion Virginia Power Technical Report EE-0099, Revision 0 (AR), North Anna Instrument Tolerance Document.

5.12 Dominion Virginia Power Technical Report EE-0100, Revision 2 with Appendices 12 and 18.

5.13 Dominion Virginia Power Technical Report EE-0085, Revision 2 with Appendices 12 and 18 5.14 Engineering Transmittal CEE 95-037, Revision 2, Transmittal of Surveillance Limits for RPS and ESFAS Primary Trip Functions at Surry Power Station Units 1 and 2, Dated 03-20-02.

5.15 Dominion Virginia Power Calculation EE-0063, Revision 2, Setpoint Accuracy for Power Range Neutron Flux High Setpoint Reactor Trip, North Anna Power Station, Units 1 and 2.

5.16 Dominion Virginia Power Calculation EE-0738, Revision 1, Add. 00A, NIS Intermediate Range Channel Statistical Allowance Calculation.

EE-0116 Page 192 of 199 Revision 5 5.17 Dominion Virginia Power Calculation EE-0710, Revision 0, North Anna Nuclear Instrumentation Source Range Uncertainty.

5.18 Dominion Virginia Power Calculation EE-0434, Revision 2, Delta T and T AVG Protection Loops, T-412, T-422 and T-432, North Anna Power Station, Units 1 and 2.

5.19 Dominion Virginia Power Calculation EE-0069, Revision 3, with Add 00A, Setpoint and Indication Accuracy for Pressurizer Pressure Loops.

5.20 Dominion Virginia Power Calculation EE-0058, Revision 2, CSA for North Anna Pressurizer Level Protection & Indication CSA.

5.21 Dominion Virginia Power Calculation EE-0060, Revision 3, CSA for North Anna Power Station Units 1 &

2 Reactor Coolant Flow Protection.

5.22 Dominion Virginia Power Calculation EE-0492, Revision 2, with Add. 00A, CSA Calculation for North Anna Power Station, Steam Generator Narrow Range Level, Units 1 & 2, Loops L-1474, L-1475, L-1476, L-1484, L-1485, L-1486, L-1494, L-1495, L-1496, L-2474, L-2475, L-2476, L-2484, L-2485, L-2486, L-2494, L-2495, & L-2496.

5.23 Dominion Virginia Power Calculation EE-0736, Revision 5, Channel Uncertainty for North Anna Units 1&2 Feedwater Flow and Steam Flow Channels Including Channel Check Criteria for Feedwater and Steam Flow Indication.

5.24 Dominion Virginia Power Calculation EE-0524, Revision 0 with Add. 0A and 0B, Reactor Coolant Pump Undervoltage and Underfrequency Trip Setpoints.

5.25 Dominion Virginia Power Calculation EE-0052, Revision 2, with Add. 00A, North Anna Containment Narrow Range Pressure Uncertainty.

5.26 Dominion Virginia Power Calculation EE-0121, Revision 3, with Add. 00A North Anna Main Steam Pressure Protection Channel Uncertainty.

5.27 Dominion Virginia Power Calculation EE-0092, Revision 4, North Anna Refueling Water Storage Tank Level Uncertainty - Wide Range.

5.28 Dominion Virginia Power Calculation EE-0198, Revision 1 with Add. 1A, Setpoint Accuracy for Power Range Neutron Flux High Setpoint Reactor Trip.

5.29 Dominion Virginia Power Calculation EE-0722, Revision 1, NIS Intermediate Range Channel Statistical Allowance Calculation.

5.30 Dominion Virginia Power Calculation EE-0719, Revision 0, Surry Nuclear Instrumentation Source Range Uncertainty.

EE-0116 Page 193 of 199 Revision 5 5.31 Dominion Virginia Power Calculation EE-0415, Revision 2, Delta T and T Average Protection Loops, T-412, T-422 and T-432, Surry Power Station, Units 1 and 2.

5.32 Dominion Virginia Power Calculation EE-0514, Revision 1, Pressurizer Pressure Protection and Indication Uncertainties CSA.

5.33 Dominion Virginia Power Calculation EE-0458, Revision 1, with Add. 00A and 00B, Channel Statistical Allowance (CSA) Calculation for Surry Pressurizer Level Protection, Surry Units 1 and 2.

5.34 Dominion Virginia Power Calculation EE-0183, Revision 3, with Add. 00A, CSA Calculation for Surry Power Station Units 1 and 2 Reactor Coolant Flow.

5.35 Dominion Virginia Power Calculation EE-0432, Revision 4 with Add. 00A, CSA Calculation for Surry Power Station, Steam Generator Narrow Range Level, Units 1&2, Loops L-1474, L-1475, L-1476, L-1484, L-1485, L-1486, L-1494, L-1495, L-1496, L-2474, L-2475, L-2476, L-2484, L-2485, L-2486, L-2494, L-2495, L-2496.

5.36 Dominion Virginia Power Calculation EE-0355, Revision 3, with Add. 03A, 00B, 00C, and 00D, Channel Uncertainty Calculation for Surry, Units 1&2 Feedwater Flow, Steam Flow, Steam Pressure and Steam Header Pressure Protection and Control Including Channel Check Criteria for Feedwater and Steam Flow Indication.

5.37 Dominion Virginia Power Calculation EE-0412, Revision 0, with Add. 0A and 0B, Reactor Coolant Pump Undervoltage and Underfrequency Trip Setpoints.

5.38 Dominion Virginia Power Calculation EE-0457, Revision 1, CSA Calculation for Turbine First Stage Pressure, Steam Break Protection and High Steam Flow SI Actuation, Surry Power Station Units 1 and 2.

5.39 Dominion Virginia Power Calculation EE-0131, Revision 4, SPS Reactor Containment Pressure: Narrow Range Pressure Indication and Protection CSA.

5.40 Dominion Virginia Power Calculation EE-0141, Revision 1, Insulation Resistance (IR) Effects for Environmentally Qualified (EQ) Instrumentation.

5.41 Dominion Virginia Power Calculation EE-0112, Revision 2, with Add. 00A, Refueling Water Storage Tank Level Uncertainty.

5.42 Dominion Virginia Power Calculation EE-0724, Revision 0, Canal Level Probe Channel Statistical Accuracy Calculation Channel Numbers: 1-CW-LS-102. 1-CW-LS-103. 2-CW-LS-202. 2-CW-LS-203.

5.43 ISA-RP67.04.02-2000, Methodologies for the Determination of Setpoints for Nuclear Safety-Related Instrumentation.

5.44 North Anna Instrument Calibration Procedure 1-ICP-RC-P-1455, Revision 4, Pressurizer Pressure Protection Channel 1 (1-RC-P-1455) Calibration.

EE-0116 Page 194 of 199 Revision 5 5.45 North Anna Instrument Calibration Procedure 1-ICP-LO-PS-609-4, Revision 11, Reactor Trip From Turbine Trip Auto Stop Oil Pressure Switch (LO-PS-609-4) Calibration.

5.46 North Anna Instrument Calibration Procedure ICP-NI-1-N-41, Revision 36, Power Range Channel N-41 Protection Channel I.

5.47 North Anna Instrument Calibration Procedure ICP-RC-1-T-1412, Revision 33, Reactor Coolant Delta T/

TAVG Protection Channel I (1-RC-T-1412) Calibration.

5.48 North Anna Instrument Calibration Procedure 1-ICP-FW-L-1474, Revision 15, Steam Generator A Narrow Range Level Protection Channel I (1-FW-L-1474) Calibration.

5.49 North Anna Instrument Calibration Procedure 1-ICP-MS-F-1474, Revision 24, Steam Generator A Steam Flow and Feed Flow Protection Channel III (1-MS-F-1474 and 1-FW-F-1477) Calibration.

5.50 North Anna Instrument Calibration Procedure 1-ICP-MS-P-1474, Revision 6, Steam Line A Steam Pressure Protection Channel II (1-MS-P-1474) Calibration.

5.51 North Anna Instrument Calibration Procedure 1-ICP-NI-N-31, Revision 8, NIS Source Range Channel I (N-31) Calibration.

5.52 North Anna Instrument Calibration Procedure 1-ICP-QS-L-100A, Revision 10, Refueling Water Storage Tank Level Channel III (1-QS-L-100A) Calibration.

5.53 North Anna Instrument Calibration Procedure 1-ICP-RC-F-1414, Revision 4, Reactor Coolant Flow Loop A Protection Channel I (1-RC-F-1414) Calibration.

5.54 North Anna Instrument Calibration Procedure 1-ICP-RC-L-1459, Revision 4, Pressurizer Level Protection Channel 1 (1-RC-L-1459) Calibration.

5.55 North Anna Instrument Calibration Procedure 1-ICP-LM-P-100B, Revision 2, Reactor Containment Pressure Protection Channel II (1-LM-P-100B) Calibration.

5.56 North Anna Instrument Calibration Procedure ICP-MS-1-P-1446A, Revision 20, P-1446A, First Stage Pressure Protection Channel III (1-MS-P-1446A) Calibration.

5.57 North Anna Instrument Calibration Procedure ICP-NI-1-N-35, Revision 22, Intermediate Range Channel N-35.

5.58 Surry Instrument Periodic Test Procedure 1-IPT-CC-CS-L-100A, Revision 7, Refueling Water Storage Tank Level Loop L-100A Channel Calibration.

5.59 Surry Instrument Periodic Test Procedure 1-IPT-CC-FW-F-476, Revision 13, Feedwater Flow Loop F 476 Channel Calibration.

EE-0116 Page 195 of 199 Revision 5 5.60 Surry Instrument Periodic Test Procedure 1-IPT-CC-FW-L-474, Revision 10, Steam Generator Level Protection Loop L-1-474 Channel Calibration.

5.61 Surry Instrument Periodic Test Procedure 1-IPT-CC-LM-P-100A, Revision 11, Containment Pressure Loop P-LM-100A Channel Calibration.

5.62 Surry Instrument Periodic Test Procedure 1-IPT-CC-MS-F-474, Revision 14, Steam Line Flow Protection Loop F-1-474 Channel Calibration.

5.63 Surry Instrument Periodic Test Procedure 1-IPT-CC-MS-P-446, Revision 13, Turbine Load Loop P-1-446 Channel Calibration.

5.64 Surry Instrument Periodic Test Procedure 1-IPT-CC-MS-P-464, Revision 3, Steam Header Pressure Loop P-1-464 Channel Calibration.

5.65 Surry Instrument Periodic Test Procedure 1-IPT-CC-MS-P-474, Revision 8, Steam Line Pressure Loop P-1-474 Channel Calibration.

5.66 Surry Instrument Periodic Test Procedure 1-IPT-CC-RC-F-414, Revision 10, Reactor Coolant Flow Loop F-1-414 Channel Calibration.

5.67 Surry Instrument Periodic Test Procedure 1-IPT-CC-RC-L-459, Revision 17, Pressurizer Level Protection Loop L-1-459 Channel Calibration.

5.68 Surry Instrument Periodic Test Procedure 1-IPT-CC-RC-P-455, Revision 12, Pressurizer Pressure Protection Loop P-1-455 Channel Calibration.

5.69 Surry Instrument Periodic Test Procedure 1-IPT-CC-RC-T-412, Revision 29, Delta T and TAVG Protection Set I Loop T-1-412 Channel Calibration.

5.70 North Anna Maintenance Operating Procedure 1-MOP-55.80, Revision 5, Turbine Stop Valve Closure Position Indication Instrumentation.

5.71 Engineering Transmittal ET-NAF-970142, Revision 0, Surry Technical Specification 3.2 Limiting Safety Settings, Protective Instrumentation Modification to Surveillance Procedures Surry Power Station Units 1 and 2.

5.72 Engineering Transmittal CEE-97-029, Revision 0, Comments on NAF Engineering Transmittal ET-NAF-970142, Revision 0 (DRAFT), Surry Power Station Units 1 & 2.

5.73 Technical Report EE-0068, Revision 0 (AR), Instrument Tolerances for Westinghouse/Hagan 7100 Process Protection and Control System, Surry Power Station.

5.74 Calculation SM-932, Revision 0, with Add. 00A and 00B, Surry Core Uprating Rod Withdrawal at Power.

EE-0116 Page 196 of 199 Revision 5 5.75 Calculation SM-0933, Revision 0, Generation of OTT, OPT and F(I) Function Constants for Surry Core Uprating.

5.76 NAF Technical Report NE-680, Revision 1, Analysis and Evaluations Supporting Implementation of STAT DNB and a 1.62 Fh at Surry Units 1 and 2.

5.77 59-DCP-06-013, NRC GSI-191, RWST Level ESFAS Function to Support Containment Sump Modifications / North Anna / Unit 2.

5.78 Engineering Transmittal CEE 98-005, Revision 0, Intake Canal Level Trip Setpoint Procedural Changes, Surry Power Station, Units 1 and 2.

5.79 Calculation ME-0318, Revision. 0, Add. 0A, Canal Level Probe Response Time.

5.80 Surry Instrument Periodic Test Procedure 1-IPT-CC-CW-L-102, Revision 10, Intake Canal Level Probe 1-CW-LS-102 Time Response Test and Channel Calibration.

5.81 Surry Instrument Periodic Test Procedure 1-PT-1.2, Revision 21, NIS Power Range Trip Channel Test.

5.82 Surry Instrument Periodic Test Procedure 1-PT-1.1, Revision 36, NIS Trip Channel Test Prior to Start-up.

5.83 Technical Report NE-1460, Revision 1, Implementation of GOTHIC Containment Analyses and Revisions to the LOCA Alternate Source Term Analysis to Support Resolution of NRC GL 2004-02 for Surry Power Station, Dated July 2006.

5.84 WCAP-11203, Improved Thermal Design Procedure Instrument Uncertainties for North Anna Units 1 &

2 Core Uprating.

5.85 Engineering Transmittal CEE-06-0010, Revision 0, Determination of RWST Level Allowable Values to Support Technical Report NE-1472 and Technical Specification Change Request N-051, North Anna Units 1 and 2, Dated 8-17-06.

5.86 Technical Report NE-1472, Revision 0, Implementation of GOTHIC Containment Analyses and Revisions to the LOCA Alternate Source Term Analysis to Support Resolution of NRC GL 2004-02 for North Anna Power Station, Dated 9-27-06.

5.87 Technical Report NE-1381, Revision 0, Evaluation of Surry Power Station Reactor Coolant System Leak Rate Calculation, Dated 8-15-2003.

5.88 Engineering Transmittal ET-NAF-08-0061, Revision 0, Implementation of Revised Safety Analysis Limit for High Pressurizer Pressure Reactor Trip, North Anna Units 1 and 2, Dated 9-9-2008.

5.89 59-DCP-06-015, NRC GSI-191, RWST Level ESFAS Function to Support Containment Sump Modifications / North Anna / Unit 1.

EE-0116 Page 197 of 199 Revision 5 5.90 Technical Specifications for Kewaunee Power Station.

5.91 Dominion Calculation C11705, Revision 0, Kewaunee Unit 1 Channel Statistical Allowance (CSA)

Calculation for the Power Range Neutron Flux High Setpoint Reactor Trip, Low Setpoint Reactor Trip and the P-10 permissive.

5.92 Dominion Calculation C10982, Revision 0, Pressurizer High Level Reactor Trip CSA.

5.93 Dominion Calculation C10818, Revision 0, Kewaunee Unit 1 Pressurizer Pressure Protection Channel Statistical Allowance (CSA) Calculation.

5.94 Dominion Calculation C11865, Revision 0, Kewaunee Unit 1 Channel Statistical Allowance (CSA)

Calculation for the Overtemperature Delta T Reactor Trip, Overpower Delta T Reactor Trip, Low-Low T Average Input to Steam Line Isolation, and Low T Average Feedwater Regulator Valve Closure.

5.95 Dominion Calculation C11006, Revision 0, Containment Pressure Channel Statistical Allowance (CSA) for Safety Injection, Main Steam Isolation, and Containment Spray Initiation.

5.96 Dominion Calculation C10819, Revision 0, Kewaunee Unit 1 Reactor Coolant Low Flow Reactor Trip Channel Statistical Allowance (CSA) Calculation.

5.97 Dominion Calculation C11116, Revision 0, Kewaunee Unit 1 Steam Generator Narrow Range Level Protection Channel Statistical Allowance (CSA) Calculation.

5.98 Dominion Calculation C10854, Revision 0, Hi & Hi-Hi Steam Flow and Low Steam Line Pressure ESF Actuation CSA.

5.99 Technical Specification Task Force Improved Standard Technical Specifications Traveler, TSTF-493, Clarify Application of Setpoint Methodology for LSSS Functions, Revision 4.

5.100 NRC Regulatory Issue Summary 2006-17, NRC Staff Position on the Requirements of 10 CFR 50.36, Technical Specifications, Regarding Limiting Safety System Settings During Periodic Testing and Calibration of Instrument Channels.

5.101 Kewaunee Calculation C11220, Revision ORIG, Determination of Forebay Low-Low- Level Trip Instrument Accuracy.

5.102 Dominion Calculation C11709, Revision 1, Addendum A, Degraded and Loss of Voltage Relay Settings, Kewaunee Power Station.

5.103 Kewaunee Surveillance Procedure SP-48-003E, Revision 17, Nuclear Power Range Channel 1 (Red) N-41 Monthly Test.

5.104 Kewaunee Surveillance Procedure SP-48-004A, Revision 27, Nuclear Power Range Channel 1 (Red) N-41 Calibration.

EE-0116 Page 198 of 199 Revision 5 5.105 Kewaunee Surveillance Procedure SP-47-011A, Revision 20, Reactor Coolant Temperature and Pressurizer Pressure Instrument Channel 1 (Red) Calibration.

5.106 Kewaunee Surveillance Procedure SP-36-014B-1, Revision D, Reactor Coolant Flow Channel 411 (Red) Instrument Calibration.

5.107 Kewaunee Surveillance Procedure SP-06-031A-1, Revision 3, Steam Generator Steam Pressure Loop 468 Transmitter Channel 1 (Red) Calibration.

5.108 Kewaunee Surveillance Procedure SP-06-034B-1, Revision 13, Steam Generator Flow Mismatch and Steam Pressure Instrument Channel 1 (Red) Calibration.

5.109 Kewaunee Surveillance Procedure SP-36-017B-1, Revision 2, Pressurizer Level Instrument Channel 426 (Red) Calibration.

5.110 Kewaunee Surveillance Procedure SP-18-043, Revision 27, Containment Pressure Instrument Channels Test.

5.111 Kewaunee Surveillance Procedure SP-18-044B, Revision 23, Containment Pressure Instrument Calibration.

5.112 Kewaunee Surveillance Procedure SP-05A-028B-3, Revision 3, Steam Generator Level Instrument Channel 463 (Yellow) Calibration.

5.113 Kewaunee Power Station Offsite Dose Calculation Manual (ODCM), Revision 11, February 22, 2007.

5.114 Kewaunee Power Station Updated Safety Analysis Report, Revision 21.3, dated 6/30/09.

5.115 Kewaunee Calculation C10690, Revision A, ODCM Setpoint Calculations.

5.116 Kewaunee Surveillance Procedure SP-48-287A-4, Revision 13, Intermediate Range N-35 Drawer Calibration.

5.117 Kewaunee Surveillance Procedure SP-48-287A-1, Revision G, Source Range N-31 Drawer Calibration.

5.118 ISA-RP67.04-Part II-1994, Methodologies for the Determination of Setpoints for Nuclear Safety-Related Instrumentation.

5.119 Surry Technical Specification Change Request No. 318 (Revised Setting Limits and Overtemperature &

Overpower T Time Constants) Licensing Amendments DPR-32 Amendment No. 261 and DPR-37 Amendment No. 261.

5.120 Technical Report No. EE-0039 Revision 0, Flow Channel Uncertainties, North Anna and Surry Power Stations.

EE-0116 Page 199 of 199 Revision 5 5.121 Kewaunee Surveillance Procedure SP-04-135, Revision 20, Forebay Area Water Level Instruments Calibration.

5.122 Kewaunee Surveillance Procedure SP-45-049.11, Revision 21, RMS Channel R-11 Containment Particulate Radiation Monitor Quarterly Functional Test.

5.123 Kewaunee Surveillance Procedure SP-45-049.12, Revision Z, RMS Channel R-12 Containment Gas Radiation Monitor Quarterly Functional Test.

5.124 Kewaunee Integrated Logic Diagram Radiation Monitoring E-2021, Revision AG.

5.125 Kewaunee Instrument Calibration Procedure MA-KW-ISP-RM-001-23, Revision 1, RMS Channel R-23 Control Room Ventilation Radiation Monitor Quarterly Functional Test.

5.126 Dominion Calculation C11890, Revision 0, Kewaunee Unit 1 Reactor Coolant Pump Underfrequency Trip Channel Statistical Allowance (CSA) Calculation.

5.127 Kewaunee Electrical Surveillance Procedure MA-KW-ESP-EHV-001A, Revision 3, BUS 1-1 4KV Voltage and Frequency Test and Calibration.

5.128 Dominion Calculation C11891, Revision 0, Kewaunee Unit 1 Reactor Coolant Pump Undervoltage Reactor Trip Channel Statistical Allowance (CSA) Calculation.

5.129 Kewaunee Electrical Preventive Maintenance Procedure MA-KW-EPM-EHV-015, Revision 0, BUS 1-5 Loss of Voltage Relay Calibration.

5.130 Kewaunee Drawing XK-100-621, Revision 3N, Interconnection Wiring Diagram.

5.131 Kewaunee DCR 2172, Provide Overall System Upgrade of Process and Area Rad Monitoring Systems.

5.132 Kewaunee Surveillance Procedure SP-54-059, Revision 29, Turbine First Stage Pressure Loop Calibration.

5.133 Kewaunee Power Station Technical Requirements Manual, Core Operating Limits Report (COLR)

Cycle 29, Revision 2.

5.134 Kewaunee Alarm Response Procedure OP-KW-ARP-47062-A, Revision 0, S/G A Program Level Deviation.

5.135 Kewaunee Drawing E-2006, Revision T, Integrated Logic Diagram Feedwater System.

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