RA-23-0120, Supplemental Information Regarding Addition of Feedwater Isolation on Steam Generator Level High-High to Technical Specification 3.3.2
| ML23151A251 | |
| Person / Time | |
|---|---|
| Site: | Robinson  |
| Issue date: | 05/31/2023 |
| From: | Basta L Duke Energy Progress |
| To: | Office of Nuclear Reactor Regulation, Document Control Desk |
| References | |
| RA-23-0120 | |
| Download: ML23151A251 (1) | |
Text
{{#Wiki_filter:Laura A. Basta H. B. Robinson Steam Electric Plant Unit No. 2 Site Vice President Duke Energy 3581 West Entrance Road Hartsville, SC 29550 843 951 1701 Laura.Basta@duke-energy.com Serial: RA-23-0120 10 CFR 50.90 May 31, 2023 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 DOCKET NO. 50-261 / RENEWED LICENSE NO. DPR-23
SUBJECT:
Supplemental Information Regarding Addition of Feedwater Isolation on Steam Generator Level High-High to Technical Specification 3.
3.2 REFERENCES
- 1. Duke Energy letter, License Amendment Request to Add Feedwater Isolation on Steam Generator Level High-High to Technical Specification 3.3.2 and Update the List of Analytical Methods Used in the Determination of Core Operating Limits, dated September 21, 2022 (ADAMS Accession No. ML22264A149)
- 2. NRC email, Request for Additional Information to Duke's Request for Robinson to Add Feedwater Isolation Function to TS 3.3.2 and Remove Obsolete Content from TSs 2.1.1.1 and 5.6.5.b (EPID L-2022-LLA-0137), dated January 11, 2023 (ADAMS Accession No. ML23011A015)
- 3. Duke Energy letter, Response to Request for Additional Information (RAI) Regarding Addition of Feedwater Isolation on Steam Generator Level High-High to Technical Specification 3.3.2, dated February 9, 2023 (ADAMS Accession No. ML23040A426)
Ladies and Gentlemen: In Reference 1, Duke Energy Progress, LLC (Duke Energy) submitted a license amendment request (LAR) to modify the Technical Specifications (TS) for H. B. Robinson Steam Electric Plant (RNP), Unit No. 2. The proposed amendment would add a new function to TS 3.3.2, Engineered Safety Feature Actuation System (ESFAS) Instrumentation, Table 3.3.2-1 for Feedwater Isolation on Steam Generator (SG) level high-high (i.e., SG overfill protection). In addition, proposed revisions to TS 2.1.1.1 and TS 5.6.5.b were included to reflect the removal of analytical methods no longer applicable for the determination of RNP core operating limits. In Reference 2, the Nuclear Regulatory Commission (NRC) staff requested additional information regarding Reference 1. Duke Energy responded to the Reference 2 request for additional information (RAI) in Reference 3. ( ~ DUKE ENERGY
U.S. Nuclear Regulatory Commission RA-23-0120 Page 2 In the Reference 1 LAR, the following was stated regarding the Allowable Value (AV) for the high-high SG level setpoint: The AV associated with this setpoint is computed as follows: AV SP + GAFT, where SP = calibrated setpoint AV 75% Span + 1.16% Span AV 76.16% Span of Reference 3 provided RNP calculation RNP-I/INST-1070, Steam Generator Narrow Range Level Loop Uncertainty and Scaling Calculation, Revision 14. Section 8.0 of RNP-I/INST-1070, Revision 14 stated (note the opposite inequality sign compared to the Reference 1 equation above): the Allowable Value (AV) associated with this setpoint is computed as follows: AV SP + GAFT, where SP = calibrated setpoint AV 75% Span + 1.16% Span AV 76.16% Span In order to clarify computation of the AV limit as well as the acceptable surveillance measured setpoint range, RNP-I/INST-1070 has been revised. Revision 16 of RNP-I/INST-1070 is provided in Attachment 1 of this letter and provides the appropriate clarification in Section 8.0. Note that changes made to RNP-I/INST-1070 are described in the revision summary included in RNP-I/INST-1070 and notated with revision numbering and revision bars on affected pages. The conclusions of the No Significant Hazards Consideration and Environmental Consideration in the original LAR are unaffected by this supplemental information. This submittal contains no new regulatory commitments. Duke Energy is notifying the state of South Carolina by transmitting a copy of this letter to the state official. Should you have any questions concerning this letter, or require additional information, please contact Ryan Treadway, Director - Nuclear Fleet Licensing, at 980-373-5873.
U.S. Nuclear Regulatory Commission RA-23-0120 Page 3 I declare under penalty of perjury that the foregoing is true and correct. Executed on May 31, 2023. Sincerely, Laura A. Basta Site Vice President Attachments:
- 1. RNP-I/INST-1070, "Steam Generator Narrow Range Level Loop Uncertainty and Scaling Calculation," Revision 16 cc:
(all with Enclosure) L. Dudes, Regional Administrator USNRC Region II J. Zeiler, NRC Senior Resident Inspector L. Haeg, NRR Project Manager M. Mahoney, NRR Project Manager A. Wilson, Attorney General (SC) R. S. Mack, Assistant Bureau Chief, Bureau of Environmental Health Services (SC) L. Garner, Manager, Radioactive and Infectious Waste Management Section (SC) RA-23-0120 RNP-I/INST-1070, Steam Generator Narrow Range Level Loop Uncertainty and Scaling Calculation, Revision 16 (124 pages follow)
Facility Code : Applicable Facilities : Document Number : Document Revision Number : Document EC Number : Change Reason : Document Title : Notes : 5/17/2023 Supervisor Abbott, Jeff 5/17/2023 Design Verifier Ray, Christy L 5/17/2023 Preparer Daji, Vijay D STEAM GENERATOR NARROW RANGE LEVEL LOOP UNCERTAINTY AND SCALING CALCULATION AD-EG-ALL-1117 016 RNP-I/INST-1070 RNP RNP (_~DUKE <{; ENERGY..
RNP-I/INST-1070, Revision 16 Page i of x Calculation Cover Sheet Steam Generator Narrow Range Level Loop Uncertainty and Scaling Calculation (LT-474, LT-475, LT-476, LT-484, LT-485, LT-486, LT-494, LT-495, LT-496) Title including structures, systems, and components Calculation Number: RNP-I/INST-1070 Rev # 16 System: 3005 DSD List: Yes No [BNP, HNP, RNP] Sub-Type: IE Microfiche Attachment List: Yes No Quality Level A Priority E: Yes No All BNP Unit CNS Unit HNP Unit MNS Unit ONS Unit RNP Unit _2___________ WLS Unit HAR Unit General Office Keowee Hydro Station Originated By Design Verification Review By Approved By Signature Signature Signature Electronically Approved Electronically Approved Electronically Approved Verification Method 1 2 3 Other Printed Name Printed Name Printed Name Vijay Daji Christy Ray Jeff Abbott Date Date Date Electronically Dated Electronically Dated Electronically Dated YES NO Check Box for Multiple Originators or Design Verifiers (see next page) For Vendor Calculations: Vendor: Vendor Document #: Owner's Review By: Date: Approval By: Date: ~
RNP-I/INST-1070, Revision 16 Page ii of x LIST OF AFFECTED PAGES Calculation Number: RNP-I/INST-1070 Revision Number: 16 Body of Calculation (including appendices) Supporting Documents Rev. # Pages Revised Pages Deleted Pages Added Rev. # Type Pages Revised Pages Deleted Pages Added 14 i - x 11 Attachment A 1 14 1 - 105 3 Attachment B 1 3 Attachment C 1 3 Attachment D 1 11 Attachment E 1 11 Attachment F 2 11 Attachment G 2 14 Attachment H 1 15 ii, v, 88 15 Attachment H 1 Attachment H 1 16 ii, v, 9, 10, 87, 88, 93, 94 i i 16 Attachment H 1 Attachment H 1 I I I I I
RNP-I/INST-1070, Revision 14 Page iii of x Revision Summary Revision Summary 0 Initial Issue 1 Revised calculation to consider seismic uncertainties. The format of the calculation was revised to follow the calculation methodology presented in EGR-NGGC-0153. 2 Revised calculation to treat static pressure effects as dependent variables as required by EGR-NGGC-0153. 3 Revised to incorporate post uprate parameter values. This revision also implements Westinghouse letters NSAL-02-3 R1 and NSAL-02-4 to address additional error terms. In addition, Westinghouse letter PGN-02-59, SG Water Level Fluid Velocity Effect Term Reduction was incorporated into setpoint analyses in this calculation. Changed recorder to the Yokogawa VR204 to reflect changes from EC 47208. 4 Revised calculation to update reference to HBR2-11260 per EC 3604. Verified containment reanalysis assumptions are included in the calculation. 5 Revised to incorporate changes from NSAL 03-09 and WCAP-161115-P as evaluated in Engineering Change 59047 and incorporate new IR values as determined by RNP-I/EQ-1175. 6 Revised calculation to address NCR 035247 (Hagan Room Temperature issue) as well as the increase in maximum control room temperature (AR 00359636). In addition, the instrument uncertainty calculation for use in EOP setpoint calculations has been modified to address the maximum containment temperature assumed when normal containment setpoints are used in the EOPs. Also since EOP setpoints are rounded to the nearest half division in the conservative direction, the need to include readability errors in the determination of the instrument uncertainty is not necessary. Thus, the readability error has been removed from the uncertainty calculation. The format of the calculation was also modified slightly and is consistent with EGR-NGGC-0017, Rev. 7. This calculation was revised as a portion of EC 83170. 7 High Steam Generator valve interlock setpoint revised to High Steam Generator alarm setpoint on p. 88 of calculation per AR 596218. 8 Revised calculation to support setpoint changes associated with Zachrys Numerical Analysis Division calculation NAI-1664-005 Containment Analysis with GOTHIC. NAI-1664-005 calculates a new maximum containment temperature following an accident, changing the existing assumption in Section 5.2 from 280°F to 340°F. This calculation was revised as a portion of EC 80767, Attachment E. Added Design Input explaining calculation of Specific Gravity. Calculation forms updated to EGR-NGGC-0017 Rev. 8. In Section 6.4.2 Summary, the Negative accPME %Span values for 30% and 50% fluid height were incorrect in Revision 7 (they were not used for any EOP setpoint values); these have been corrected in Revision 8 (the values did not include FRE) (See NCR 620161). 9 Calculation was revised for changes due to EC 75690, Deletion of the Steam Flow/Feed Flow Mismatch Reactor Trip. All information solely for the support of this trip was deleted from the calculation. There were dual output comparators which were changed to single output but no calc changes were required since specifications do not change between the 2 comparators.
RNP-I/INST-1070, Revision 14 Page iv of x 10 For EOP use, the adverse containment setpoints can be based on the maximum temperature expected when the EOP steps containing adverse containment setpoints are reached. This is at least 100 seconds after the reactor trip, so the high containment temperatures (above 280°F) that is documented in the MSLB analysis (EC 80767) will not impact the EOP setpoint. This revision to RNP-I/INST-1070 will add a calculation of the PMA at 280°F for use in the EOP Setpoint calculations. This calculation was revised as a portion of EC 83171 Revision 2. 11 Revised calculation to incorporate change at H. B. Robinson from an 18 month fuel cycle to a 24 month fuel cycle: i) added References 4.2.7, 4.2.8, 4.2.9, 4.5.13, 4.5.15 thru 4.5.21, 4.6.5, 4.7.22, 4.7.23 and 4.7.24, deleted Reference 4.7.6, and updated Reference revision levels; ii) added Design Inputs 5.26, 5.27, and 5.28; iii) added Attachments F and G and deleted Attachments A and E, iv) updated Instrument Identification Table and associated calculation Sections to reflect proper make/model numbers for installed equipment; v) incorporated transmitter and indicator analyzed drift from calculations RNP-I/INST-1212 Rev. 0 and RNP-I/INST-1215 Rev. 0 respectively; vi) re-calculated transmitter, isolator, and indicator TDUs for normal, accident and EOP conditions where applicable; vii) re-calculated indicator, recorder, ERFIS, and AMSAC TLUs for normal, accident, and EOP conditions where applicable; viii) re-calculated Low and Low Low SG Level alarm TLUs, post seismic TLU for the Hi Level Valve Interlock, and Low Low SG Level Rx Trip TLU, all requiring no setpoint changes; ix) listed impact to RNP-I/INST-1103 Rev. 5 EOP setpoints in Section 8.5; and x) performed minor editorial corrections. 12 This revision incorporates ECs 411961, 413069 and 401424 and AR 2231413, which made the following changes: EC 411961 replaced level transmitters LT-474, LT-475, LT-476, LT-484, LT-485, LT-486, LT-494, LT-495 and LT-496 with a Rosemount model 3154ND2R2F1E7. CMU EC 413069 replaced the FR-488 and FR-498 control room recorders with a DX1004N model recorder (performed under Fleet spec EC 410155). Note that previous EC 407891 replaced the FR-478 recorder with a DX1004N model recorder, but did not update this calculation for conservatism. This revision changes also FR-478 to reflect the DX1004N model that was previously installed. EC 401424 revised the containment temperature evaluations listed in RNP-I/EQ-1175, which caused downstream impacts to calculation RNP-I/INST-1070. AR 2231413 identifed that calculation RNP-I/INST-1070 Section 8 does not identify the UFSAR as a potentially impacted document. This revision revises Section 8 of this calculation to specify the UFSAR as a potentially impacted document. 13 The Plant Parameters Document (PPD) has been replaced by the Safety Analysis Inputs Manual (SAIM) Robinson Nuclear Plant (RNP) starting at Cycle 33. The new SAIM document is not an exact replacement for the PPD, and may not contain all the content once found in the PPD. Historically, PPDs have been previously issued as a Fuels calculation prior to the cycle start date, and end at the beginning of a new operating cycle when a new PPD (Fuels Calculation) is issued for the next operating cycle. The PPDs have been referenced in numerous ways in numerous documents throughout the years, from generic references to specific values listed in specific tables. In some RNP-I/INST and RNP-F/NFSA calculations, the cycle specific PPD calculation may be listed as an affected document as it may provide an input or use an output from the calculation. Starting at R2C33 RNP-I/INST calculations will be updated to clarify references to the new SAIM cycle specific document, or another document if necessary.
RNP-I/INST-1070, Revision 16 Page v of x 13 Revise Reference 4.7.3, RNP-F/NFSA-0230, RNP Cycle 30 PPD, to SAIM RNP-000, NGO Safety Analysis Inputs Manual (SAIM) Robinson Nuclear Plant (RNP). Updated Amendment for Reference 4.7.2 to 263. Updated UFSAR Revision to 28 for Reference 4.7.1. Add Reference 4.7.25 EC 415220 Revision 1, R2C33 Safety Analysis Site Implementation Revised Design Input 5.10, clarified reference to Main Steam Safety Valves versus SG Safety Relief Valves. Revised Design Input 5.13, clarified the Analytic Limit used in the Safety Analysis for the High Level Valve Interlock Setpoint. Added Reference 4.7.3 to Design Input 5.15. Reinstated Attachments on the List of Affected Pages that were inadvertently deleted in previous revision. Clarified References throughout calculation. Section 8.0, Incorporated the more conservative Steam Generator Level Valve Interlock Analytic Value (92 % Span versus 97.77% Span in the Margin Calculation. 14 In Revision 14 of this calculation file the High Steam Generator Level Valve Interlock ESFAS trip setpoint (= 75 %) is evaluated against an analytic steam generator level limit of 97% assumed in the updated RNP UFSAR Chapter 15.1.2, Increase in Feedwater Flow (IFF) transient analysis (Reference 4.2.10), performed in-house using NRC approved Duke methodology. The current UFSAR 15.1.2 IFF analysis (performed by Framatone) did not credit the above trip setpoint and therefore the setpoint is not currently included in the Technical Specifications. A license amendment request (LAR) will be submitted to the NRC to add this trip function to Technical Specification Table 3.3.2-1. Once the LAR is approved plant implementation of the trp function will be initiated. A Technical Specificaton Allowable Value (AV) is calculated for the High Steam Generator Level Valve Interlock ESFAS trip setpoint in Section 8.0. A new administrative procedure on uncertainty and setpoint analysis is incorporated via Reference 4.6.6. The former administrative procedure (Reference 4.6.1) is kept due to referenced material not available in the new administrative procedure. 15 An error discovered in the determination of the Tech. Spec. Allowable Value (AV), for the High Steam Generator Level Valve Interlock ESFAS trip setpoint, in Section 8.0, is corrected (NCR 02466713). The inequality sign for the allowable value is changed to <. The correct inequality sign was used in the LAR that was submitted to the NRC to add the High Steam Generator Valve Interlock to the Technical Specifications. Therefore, no other documents are affected by this change. 16 The following summarizes the changes made in Rev. 16: Page 9 of 105: Updated amendment number of Reference 4.7.2 to the current version. Page 10 of 105: Corrected typographical error - changes Value to Valve. Page 87/88 of 105: Calculation of the High SG Level Valve Interlock Setpoint (increasing setpoint) Allowable Value (AV) and its application is clarified. Page 93/94 of 105: Calculation of the Low Low SG Level Reactor Trip Setpoint (decreasing setpoint) Allowable Value (AV) and its application is clarified.
RNP-I/INST-1070 Revision 14 Page vi of x DOCUMENT INDEXING TABLE The purpose of this table is to create document cross-references in the Document Management System and equipment cross-references in the Equipment Data Base. Document Type Document Number Function Relationship to this Calculation Action CALC INST-I/INST-1212 IN Reference ADD/RETAIN CALC INST-I/INST-1215 IN Reference ADD/RETAIN PROC MST-013 IN Reference ADD/RETAIN PROC PIC-005-1 IN Reference ADD/RETAIN PROC PIC-005-2 IN Reference ADD/RETAIN PROC PIC-005-4 IN Reference ADD/RETAIN PROC PIC-005-6 IN Reference ADD/RETAIN PROC PIC-005-8 IN Reference ADD/RETAIN PROC PIC-005-9 IN Reference ADD/RETAIN PROC PIC-005-10 IN Reference ADD/RETAIN PROC EOP-ECA-0.0 IN Reference ADD/RETAIN PCHG EC 97661 IN Reference ADD/RETAIN CALC RNP-M/MECH-1651 OUT Document affected by results ADD/RETAIN NF SAIM RNP-000 IN Reference ADD/RETAIN
RNP-I/INST-1070, Revision 14 Page vii of x Table of Contents SEC DESCRIPTION PAGE 1.0 OBJECTIVE..............................................................................................................................1 2.0 FUNCTIONAL DESCRIPTION...............................................................................................3 2.1 Normal Function...............................................................................................................3 2.2 Accident Mitigating Function...........................................................................................3 2.3 Post Accident Monitoring Function..................................................................................3 2.4 Post Seismic Function.......................................................................................................3 3.0 LOOP DIAGRAM.....................................................................................................................4
4.0 REFERENCES
..........................................................................................................................7 4.1 Drawings...........................................................................................................................7 4.2 Calculations.......................................................................................................................7 4.3 Regulatory Documents......................................................................................................7 4.4 Technical Manuals............................................................................................................8 4.5 Calibration And Maintenance Procedures........................................................................8 4.6 Procedures.........................................................................................................................9 4.7 Other References...............................................................................................................9 5.0 INPUTS AND ASSUMPTIONS.............................................................................................11 6.0 CALCULATION OF UNCERTAINTY CONTRIBUTORS..................................................19 6.1 ACCIDENT EFFECTS (AE).............................................................................................19 6.1.1 Accident Temperature Effect (ATE)........................................................................19 6.1.2 Accident Pressure Effect (APE)................................................................................20 6.1.3 Accident Radiation Effect (ARE).............................................................................20 6.2 SEISMIC EFFECT (SE)....................................................................................................20 6.3 INSULATION RESISTANCE ERROR (IR)....................................................................20 6.4 PROCESS MEASUREMENT ERROR (PME).................................................................21 6.4.1 Process Measurement Error - Normal Environment.................................................21 6.4.2 Process Measurement Error - Accident Environment..............................................29 6.4.3 Process Measurement Error - Normal Environment for EOP Use...........................37 6.4.4 Process Measurement Error - Accident Environment for EOPs...............................44 6.5 PRIMARY ELEMENT ERROR (PE)............................................................................46 6.6 Transmitter......................................................................................................................46 6.6.1 Transmitters Unverified Attributes of Reference Accuracy (RAxmtr)......................46 6.6.2 Transmitter Calibration Tolerance (CALxmtr)...........................................................46 6.6.3 Transmitter Drift (DRxmtr).........................................................................................47 6.6.4 Transmitter M&TE Effect (MTExmtr).......................................................................47 6.6.5 Transmitter Temperature Effect (TExmtr)..................................................................48 6.6.6 Normal Transmitter Static Pressure Effect (norSPExmtr)..........................................49 6.6.7 Accident Transmitter Static Pressure Effect (accSPExmtr)........................................50 6.6.8 Transmitter Power Supply Effect (PSExmtr)..............................................................50 6.6.9 Normal Transmitter Total Device Uncertainty (norTDUxmtr)...................................51 6.6.10 Normal Transmitter Total Device Uncertainty (eopTDUxmtr) for EOPs.................51 6.6.11 Accident Transmitter Total Device Uncertainty (accTDUxmtr)...............................51 6.6.12 Transmitter As Found Tolerance (AFTxmtr)............................................................52 6.6.13 Transmitter As Left Tolerance (AL Txmtr)..............................................................53 6.7 COMPARATOR MODULE...........................................................................................54
RNP-I/INST-1070, Revision 14 Page viii of x 6.7.1 Comparators Unverified Attributes of Reference Accuracy (RAcomp)....................54 6.7.2 Comparator Calibration Tolerance (CALcomp)..........................................................54 6.7.3 Comparator Drift (DRcomp)........................................................................................54 6.7.4 Comparator M&TE Effect (MTEcomp)......................................................................55 6.7.5 Comparator Temperature Effect (TEcomp).................................................................55 6.7.6 Comparator Power Supply Effect (PSEcomp).............................................................55 6.7.7 Comparator Total Device Uncertainty (TDUcomp)....................................................55 6.7.8 Comparator As Found Tolerance (AFTcomp).............................................................56 6.7.9 Comparator As Left Tolerance (ALTcomp)................................................................56 6.8 ISOLATOR MODULE...................................................................................................57 6.8.1 Isolators Unverified Attributes of Reference Accuracy (RAisol).............................57 6.8.2 Isolator Calibration Tolerance (CALisol)...................................................................57 6.8.3 Isolator Drift (DRisol)................................................................................................57 6.8.5 Isolator Temperature Effect (TEisol)..........................................................................58 6.8.6 Isolator Power Supply Effect (PSEisol)......................................................................59 6.8.7 Isolator Total Device Uncertainty (TDUisol).............................................................60 6.8.8 Isolator As Found Tolerance (AFTisol)......................................................................61 6.8.9 Isolator As Left Tolerance (ALTisol).........................................................................61 6.9 INDICATOR......................................................................................................................63 6.9.1 Indicators Unverified Attributes of Reference Accuracy (RAind)...........................63 6.9.2 Indicator Calibration Tolerance (CALind).................................................................63 6.9.3 Indicator Drift (DRind)...............................................................................................63 6.9.5 Indicator Temperature Effect (TEind)........................................................................64 6.9.6 Indicator Power Supply Effect (PSEind)....................................................................64 6.9.7 Indicator Readability (RDind)....................................................................................64 6.9.8 Indicator Total Device Uncertainty (TDUind)...........................................................65 6.9.9 Indicator Total Device Uncertainty for EOP Setpoints (eopTDUind).......................65 6.9.10 Indicator As Found Tolerance (AFTind)..................................................................66 6.9.11 Indicator As Left Tolerance (ALTind).....................................................................67 6.10 RECORDER....................................................................................................................68 6.10.1 Recorders Unverified Attributes of Reference Accuracy (RArec).........................68 6.10.2 Recorder Calibration Tolerance (CALrec)...............................................................68 6.10.3 Recorder Drift (DRrec).............................................................................................69 6.10.4 Recorder M&TE Effect (MTErec)...........................................................................69 6.10.5 Recorder Temperature Effect (TErec)......................................................................69 6.10.6 Recorder Power Supply Effect (PSErec)..................................................................69 6.10.7 Recorder Readability (RDrec)..................................................................................70 6.10.8 Recorder Total Device Uncertainty (TDUrec).........................................................70 6.10.9 Recorder As-Found Tolerance (AFTrec)................................................................70 6.10.10 Recorder As Left Tolerance (ALTrec)..................................................................71 7.0 TOTAL LOOP UNCERTAINTY (TLU)................................................................................72 7.1 TOTAL LOOP UNCERTAINTY - PLANT NORMAL...................................................72 7.1.1 Total Loop Uncertainty - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, & 496.............................................................................................................................72 7.1.2 Total Loop Uncertainty - Input to ERFIS.................................................................73 7.1.4 Total Loop Uncertainty - High Level Alarm............................................................75 7.1.5 Total Loop Uncertainty - Low Low Level Alarm....................................................75 7.1.6 Total Loop Uncertainty - Low Level Alarm.............................................................75 7.1.7 Total Loop Uncertainty - Input to AMSAC..............................................................75 7.2 TOTAL LOOP UNCERTAINTY - ACCIDENT...........................................................78
RNP-I/INST-1070, Revision 14 Page ix of x 7.2.1 Total Loop Uncertainty - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, & 496.............................................................................................................................78 7.2.2 Total Loop Uncertainty - Recorder...........................................................................79 7.2.3 Total Loop Uncertainty - Input to ERFIS.................................................................80 7.2.4 Total Loop Uncertainty - Low Low Level Reactor Trip..........................................81 7.2.5 Total Loop Uncertainty for use in the EOPs - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, AND 496...........................................................................................82 7.3 TOTAL LOOP UNCERTAINTY - POST SEISMIC....................................................83 7.3.1 Total Loop Uncertainty - High Level Valve Interlock.............................................83 7.4 LOOP AS FOUND TOLERANCE.................................................................................83 7.4.1 Loop As Found Tolerance - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, & 496.............................................................................................................................83 7.4.2 Loop As Found Tolerance - Input to ERFIS.............................................................83 7.4.3 Loop As Found Tolerance - Comparators................................................................84 7.4.4 Loop As Found Tolerance - Recorder......................................................................84 7.4.5 Loop As Found Tolerance - Input to AMSAC.........................................................84 7.5 GROUP AS FOUND TOLERANCE..............................................................................85 7.5.1 Group As Found Tolerance - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, & 496.............................................................................................................................85 7.5.2 Group As Found Tolerance - Input to ERFIS...........................................................85 7.5.3 Group As Found Tolerance - Recorder.....................................................................86 7.5.4 Group As Found Tolerance - Comparators...............................................................86 7.5.5 Group As Found Tolerance - Input to AMSAC........................................................86 8.0 DISCUSSION OF RESULTS.................................................................................................87 8.1 Impact On Improved Technical Specifications...............................................................95 8.2 Impact On Ufsar..............................................................................................................95 8.3 Impact On Design Basis Documents...............................................................................95 8.4 Impact On Other Calculations.........................................................................................95 8.5 Impact On Plant Procedures............................................................................................96 9.0 SCALING CALCULATIONS.................................................................................................97 9.1 Level Transmitter (LT-474, 475, 476, 484, 485, 486, 494, 495, And 496).......................97 9.2 Isolator Module (LM-474, 474A, 474B, 475, 475A, 476, 476A, 484, 484A, 485, 485A, 485B, 486, 486A, 494, 494A, 494B, 495, 495A, 496, 496A, And 496B).......................100 9.3 Comparator Module (LC-474, 475, 476, 484, 485, 486, 494, 495, & 496).....................101 9.4 Comparator Module (LC-474A, 475A, 476A, 484A, 485A, 486A, 494A, 495A, & 496A)...............................................................................................................................102 9.5 Comparator Module (LC-474B, 475B, 484B, 485B, 494B, & 495B).............................103 9.6 Indicator (LI-474, 475, 476, 484, 485, 486, 494, 495, & 496)........................................104 9.7 Recorder (FR-478, 488, & 498).......................................................................................104
RNP-I/INST-1070, Revision 14 Page x of x LIST OF ATTACHMENTS PAGES Attachment A - Deleted Attachment B - Comparator Drift 1 Attachment C - Rosemount Drift 1 Attachment D - International Instruments Indicator Data 1 Attachment E - Deleted Attachment F - NUS Instruments Long Term Drift Test for NUS Modules, Final Report Executive Summary, dated October 26, 2001 2 Attachment G - Email form NUS Confirming Similarity of NUS Isolator Modules, dated, January 15, 2002 2 Attachment H - Record of Review 1
RNP-I/INST-1070 Revision 14 Page 1 of 105 1.0 OBJECTIVE This calculation computes the loop uncertainties associated with the indication, recording, and trip functions provided by the Steam Generator Narrow Range Level instrumentation loops. The loops addressed in this calculation also provide input to the Emergency Response Facility Information System (ERFIS) and AMSAC. Uncertainties at the input to the ERFIS and AMSAC are calculated. Uncertainties are calculated for normal, accident, and seismic conditions. This calculation develops the Reactor Protection System (RPS) setpoint associated with each instrument loop. This calculation also calculates the Allowable Value for the RPS setpoint addressed in this calculation. Uncertainties associated with the control functions provided by the Steam Generator Level loops are not calculated. The RNP UFSAR Chapter 15.1.2, Increase in Feedwater Flow (IFF) transient analysis, was performed in-house in calculation file RNP-F/NFSA-0356 (Reference 4.2.10) using NRC approved Duke methodology. The analysis credited feedwater isolation on high-high SG NR level. Since this trip is not currently included in the Technical Specifications, a license amendment request (LAR) will be submitted to the NRC to add this trip to Technical Specification Table 3.3.2-1. The current UFSAR Section 15.1.2 evaluation will remain the licensing basis until the LAR is approved, at which time the analysis in this calculation file will be implemented via the markups documented in Appendices A (UFSAR Markup), B (REDSAR Markup), and C (SAIM Markup) of Reference 4.2.10. The Duke analysis performed in Reference 4.2.10 credits a conservative High Steam Generator Level Valve Interlock Analytic Value of 97%, i.e. when the level in any steam generator reaches 97% the associated main feedwater regulating valve closes and trips the main feedwater pumps. Section 8.0 of this calculation file is updated accordingly and an allowable value (AV) of the Steam Generator Level Valve Interlock setpoint is determined. The implementation of this change is managed by Reference 4.7.26.
RNP-I/INST-1070 Revision 14 Page 2 of 105 The instrument loops containing the following components are addressed in this calculation: LT-474 LQ-474 L-474 LC-474 LC-474A LM-474 LC-474B LI-474 LM-474A LM-474B LM-474/R LC-474/R LC-474A/R LT-484 LQ-484 L-484 LC-484 LC-484A LM-484 LC-484B LI-484 LM-484A LM-484/R LC-484/R LC-484A/R LT-494 LQ-494 L-494 LC-494 LC-494A LM-494 LC-494B LI-494 LM-494A LM-494/R LC-494/R LC-494A/R LT-475 LQ-475 L-475 LC-475 LC-475A LM-475 LC-475B LI-475 LM-475A LM-475A/R LC-475/R LC-475A/R LT-485 LQ-485 L-485 LC-485 LC-485A LM-485 LC-485B LI-485 LM-485A LM-485B LM-485A/R LC-485/R LC-485A/R LT-495 LQ-495 L-495 LC-495 LC-495A LM-495 LC-495B LI-495 LM-495A LM-495/R LC-495/R LC-495A/R LT-476 LQ-476 L-476 LC-476 LC-476A LM-476 LI-476 FR-478 LM-476A LM-476/R LC-476/R LC-476A/R LT-486 LQ-486 L-486 LC-486 LC-486A LM-486 LI-486 FR-488 LM-486A LM-486A/R LC-486/R LC-486A/R LT-496 LQ-496 L-496 LC-496 LC-496A LM-496 LI-496 FR-498 LM-496A LM-496B LM-496A/R LC-496/R LC-496A/R
RNP-I/INST-1070 Revision 14 Page 3 of 105 2.0 FUNCTIONAL DESCRIPTION The Steam Generator provides a heat sink for the Reactor Coolant System (RCS) during normal and accident plant operation. Feedwater occupies about half of the Steam Generator with steam filling the other half. Various events affect Steam Generator level during normal and accident operation. In the event that the normal control system is unable to maintain Steam Generator Level within the normal operating band, protective actions must be initiated to ensure that level remains within design limits during the transient. The instrument loop that is the subject of this calculation provide the following protective functions:
- Low Low Steam Generator Level Reactor Trip 2.1 Normal Function During normal operation, the instrument loops addressed in this calculation provide Steam Generator Level indication (LI-474, 475, 476, 484, 485, 486, 494, 495 & 496), recording (FR-478), and input to the Emergency Response Facility Information System (ERFIS).
These loops also provide Low Low, and High Steam Generator Level alarms, a High Steam Generator Level valve interlock, and provide input to AMSAC. 2.2 Accident Mitigating Function The instrument loop addressed in this calculation provides a Reactor Trip on Low Low Steam Generator Level. The Reactor Trip on Low Low Steam Generator Level also serves to protect against the loss of the Steam Generator as a heat sink for the RCS. A Reactor Trip and Auxiliary Feedwater System actuation occurs when two out of three Steam Generator Level signals fall below the Low Low Steam Generator Level setpoint. Per Reference 4.7.1, this trip is credited in the Safety Analysis for termination of the following events:
- Loss of non-emergency power to station auxiliaries
- Loss of normal feedwater
- Feedwater line break 2.3 Post Accident Monitoring Function Per TMM-026, these instrument loops are used for post accident monitoring.
2.4 Post Seismic Function Per Reference 4.7.14, these instruments are seismically qualified to ensure that safety / protection functions remain operable following a seismic event.
RNP-I/INST-1070 Revision 14 Page 4 of 105 3.0 LOOP DIAGRAM Note: Same configuration for loops L-475, 476, 484, 485, 486, 494, 495, and 496 except where noted.
- L-474, 485, 496 only i
. ~---~ ~------+: .... ~ ......... ~-;:~!tor)""""""""""'AMSAC..... I OHH HH NHHN............................ N O N............ NHN..............................., L-476. 486. 496 only ~~78 I l................................................................................................. ! LI-474 IND LQ-474 LM-474/R LM-474 LM-474A L-474 ERFIS Power Supply IN V /I (Isolator) I/I (Isolator) IN LC-474/R LC-474 High Level Alarm IN COMP High Level Valve Interlock LC-474A/R LC-474A Low Low Level Alarm IN COMP Low Low Level Reactor Trip f......................................................................................................................................................................................... i LC-474B Low Level Alarm i i OOMP ~---~ ! L-474, 475 !,t!:::.:~;_only..................................................................................................................................................1
RNP-I/INST-1070 Revision 14 Page 5 of 105 TAG NUMBER FUNCTION MAKE AND MODEL LOCATION REFERENCE LT-474, 475, 476 LT-484, 485, 486 LT-494, 495, 496 Transmitter Rosemount 3154ND2R2F1E7 Containment 4.1.1-8, 4.7.4 LQ-474, 475, 476 LQ-484, 485, 486 LQ-494, 495, 496 Power Supply NUS SPS 800 Hagan Rack 4.1.1-8, 4.7.4 LM-474/R, LC-474/R, 474A/R LM-475A/R LC-475/R, 475A/R LM-476/R LC-476/R, 476A/R LM-484/R, LC-484/R, 484A/R LM-485A/R LC-485/R, 485A/R LM-486A/R LC-486/R, 486A/R LM-494/R, LC-494/R, 494A/R LM-495/R LC-495/R, 495A/R LM-496A/R LC-496/R, 496A/R I/V Hagan Model 3110554-000 Hagan Rack 4.1.1-8, 4.7.4 LM-474A, 475A LM-476A, 484A LM-485A, 486A LM-494A, 495A LM-496A I/I Isolator NUS EIP-E013DD-1 Hagan Rack 4.1.1-8, 4.7.4
RNP-I/INST-1070 Revision 14 Page 6 of 105 TAG NUMBER FUNCTION MAKE AND MODEL LOCATION REFERENCE LM-474, 475, 476 LM-484, 485, 486 LM-494, 495, 496 V/I Isolator NUS OCA 800 Hagan Rack 4.1.1-8, 4.7.4 LM-474B, 485B LM-496B V/I Isolator NUS EIP-E013DD-37 Hagan Rack 4.1.1-8, 4.7.4 LC-474, 475, 476 LC-484, 485, 486 LC-494, 495, 496 LC-474A, 475A LC-476A, 484A LC-485A, 486A LC-494A, 495A LC-496A, 474B LC-475B, 484B LC-485B, 494B LC-495B Comparator Hagan Model 139-118 Or NUS SAM 800 Or NUS DAM 800 Hagan Rack 4.1.1-8, 4.7.4 LI-474, 475, 476 LI-484, 485, 486 LI-494, 495, 496 Indicator International Instruments 2520VB RTGB 4.1.1-8, 4.7.4 FR-478, 488, 498 Recorder Yokogawa DX1004N RTGB 4.7.4, 4.7.15 L-474, 475, 476 L-484, 485, 486 L-494, 495, 496 I/V Hagan Computer Signal Conditioner 3110552-000 Hagan Rack 4.1.1-8, 4.7.4 Instrument Identification
RNP-I/INST-1070 Revision 14 Page 7 of 105
4.0 REFERENCES
4.1 Drawings 4.1.1 5379-03513, Hagan Wiring Diagram, Revision 23 4.1.2 5379-03514, Hagan Wiring Diagram, Revision 25 4.1.3 5379-03515, Hagan Wiring Diagram, Revision 24 4.1.4 5379-03516, Hagan Wiring Diagram, Revision 23 4.1.5 5379-03517, Hagan Wiring Diagram, Revision 25 4.1.6 5379-03518, Hagan Wiring Diagram, Revision 25 4.1.7 5379-03485, Hagan Wiring Diagram, Revision 23 4.1.8 5379-03486, Hagan Wiring Diagram, Revision 23 4.1.9 HBR2-11260, Zone Map For Environmental Parameters Reactor Building Elevation 228 ft, Sheet 5, Revision 6 4.1.10 HBR2-11260, Zone Map For Environmental Parameters, Sheet 8, Revision 15 4.1.11 HBR2-11135, RTGB Panel C - Annunciator Section, Sheet 2, Revision 1 4.1.12 HBR2-11135, RTGB Panel C - Vertical Section, Sheet 3, Revision 2 4.1.13 A-190299, Instrument Hook-Up Detail, Sheet 46, Revision 6 4.1.14 HBR2-10731, Steam Generator Model 44F Upper Steam Drum Field Modifications, Sheet 1, Revision 0 4.1.15 HBR2-10750, #44 Series Vertical Steam Generator Outline, Revision 1 4.1.16 5379-03487, Hagan Wiring Diagram, Revision 23 4.1.17 HBR2-10736, Rev. 0, Steam Generator - Mod. "44F" Feedwater Ring & J -Nozzle Assembly 4.2 Calculations 4.2.1 RNP-E-1.005, 120 VAC Instrument Bus Voltage Evaluation, Revision 4 4.2.2 RNP-I/EQ-1175, In-CV Rosemount Transmitter Loop Accuracy, Revision 3 4.2.3 RNP-M/MECH-1651, Containment Analysis Inputs, Revision 14 4.2.4 RNP-I/INST-1103, Steam Generator Level EOP Setpoint Parameters, Revision 5 4.2.5 RNP-I/INST-1109, Containment EOP Setpoint Parameters, Setpoint M.13, Rev. 7 4.2.6 RNP-M/HVAC-1078, Hagan Room Temperature, Revision 4 4.2.7 RNP-I/INST-1212, Rosemount 1154DP4 and 1154HP5 Pressurizer and Steam Generator Narrow Range Level Transmitters Instrument Drift Analysis, Revision 0 4.2.8 RNP-I/INST-1215, Drift Analysis for International Instruments Model 2520 Indicators, Revision 0 4.2.9 RNP-I/INST-1079, Steam Generator Level AOP Setpoint Parameters, Revision 3 4.2.10 RNP-F/NFSA-0356, Rev. 0, RNP UFSAR Section 15.1.2 - Increase in Feedwater Flow 4.3 Regulatory Documents 4.3.1 Regulatory Guide 1.97, Rev. 3, Instrumentation for Light Water-Cooled Nuclear Power Plants to Assess Plant and Environs Conditions During and Following an Accident
RNP-I/INST-1070 Revision 14 Page 8 of 105 4.4 Technical Manuals 4.4.1 728-589-13, Vendor Manual Hagan, Revision 42 4.4.2 728-399-88, Auxiliary Indicating Meters Bulletin Model 2500 2520, Revision 3 4.4.3 728-012-10, Vendor Manual Rosemount, Revision 40 4.4.4 728-208-63. VERTICAL STEAM GENERATOR TECHNICAL MANUAL, Revision 22 4.4.5 DPM 1346.04-0002.001, Yokogawa Recorder Vendor Manual, Revision 0 4.5 Calibration And Maintenance Procedures 4.5.1 PIC-005, Steam Generator A Narrow Range Level Transmitter LT-474 Calibration, Revision 13 4.5.2 LP-027, Steam Generator #1 Narrow Range (N/R) Level Channel 476, Revision 16 4.5.3 LP-028, Steam Generator #2 Narrow Range (N/R) Level Channel 486, Revision 15 4.5.4 LP-029, Steam Generator #3 Narrow Range (N/R) Level Channel 496, Revision 19 4.5.5 LP-030, Steam Generator #1 Narrow Range (N/R) Level Channel 474, Revision 15 4.5.6 LP-031, Steam Generator #2 Narrow Range (N/R) Level Channel 484, Revision 15 4.5.7 LP-032, Steam Generator #3 Narrow Range (N/R) Level Channel 494, Revision 13 4.5.8 LP-033, Steam Generator #1 Narrow Range (N/R) Level Channel 475, Revision 13 4.5.9 LP-034, Steam Generator #2 Narrow Range (N/R) Level Channel 485, Revision 16 4.5.10 LP-035, Steam Generator #3 Narrow Range (N/R) Level Channel 495, Revision 13 4.5.11 MMM-006, Calibration Program, Revision 34 4.5.12 PIC-844, Yokogawa Recorders, Revision 13 4.5.13 MST-013, Steam Generator Water Level Protection Channel Testing, Revision 26 4.5.14 PIC-005-1, Steam Generator A Narrow Range Level Transmitter LT-475 Calibration, Revision 0 4.5.15 PIC-005-2, Steam Generator A Narrow Range Level Transmitter LT-476 Calibration, Revision 0 4.5.16 PIC-005-4, Steam Generator B Narrow Range Level Transmitter LT-484 Calibration, Revision 0 4.5.17 PIC-005-5, Steam Generator B Narrow Range Level Transmitter LT-485 Calibration, Revision 0 4.5.18 PIC-005-6, Steam Generator B Narrow Range Level Transmitter LT-486 Calibration, Revision 0 4.5.19 PIC-005-8, Steam Generator C Narrow Range Level Transmitter LT-494 Calibration, Revision 0 4.5.20 PIC-005-9, Steam Generator C Narrow Range Level Transmitter LT-495 Calibration, Revision 1 4.5.21 PIC-005-10, Steam Generator C Narrow Range Level Transmitter LT-96 Calibration, Revision 0
RNP-I/INST-1070 Revision 16 Page 9 of 105 4.6 Procedures 4.6.1 EGR-NGGC-0153, Engineering Instrument Setpoints, Revision 12 4.6.2 TMM-026, List of Regulatory Guide 1.97 Components, Revision 32 4.6.3 MMM-006, Apprendix B-1, Calibration Program, Revision 51 4.6.4 OP-906, Heating, Ventilation, and Air Conditioning, Rev. 72 4.6.5 EOP-ECA-0.0, Loss of All AC Power, Revision 4 4.6.6 AD-EG-ALL-1153, Engineering Instrument Setpoint/Uncertainty Calculations, Revision 0. FAD-EG-ALL-1153, DETAIL/EXAMPLE, Engineering Instrument Setpoint/Uncertainty Methodology and Discussion, Revision 0. 4.7 Other References 4.7.1 Updated Final Safety Analysis Report - Chapter 15, Revision 28. 4.7.2 Technical Specifications, Amendment 274. 4.7.3 SAIM RNP-000, Safety Analysis Inputs Manual Robinson Nuclear Plant 4.7.4 Equipment Data Base (EDB) 4.7.5 ASME Steam Tables, 5th Edition (based on the 1967 IFC formulation) 4.7.6 Deleted 4.7.7 ASME Section II-A, Table TE-1 4.7.8 ASME Section II-A, SA-302/SA-302M 4.7.9 WNEP-8372, Model 44F Steam Generator Thermal and Hydraulic Design Data Report, Revision 3, April 1, 1985 4.7.10 Letter CQL-92-031, S/G Water Level PME Term Inaccuracies, June 18, 1992 4.7.11 a. WCAP-15304, Carolina Power and Light Company H. B. Robinson Steam Electric Plant, Unit No.2 LOCA Containment Integrity Analysis.
- b. WCAP-15305, Carolina Power & Light Company H. B. Robinson Steam Electric Plant, Unit No.2 Steamline Break Containment Integrity Analysis
- c. Calculation NAI-1664-005 Containment Analysis with GOTHIC
- d. Letter to Progress Energy H.B Robinson Nuclear Plant, LOCA M&E Reanalysis to Address Elevated RWST and Accumulator Temperature Engineering Report and FSAR Markups with Attachment of Westinghouse LTR-CRA-12-19 Engineering Report Engineering Report for H.B. Robinson LOCA M&E Release Analysis, Revision 6 4.7.12 Westinghouse Nuclear Safety Advisory Letters (NSALs)
- a. NSAL-02-3 Revision 1, April 8, 2002
- b. NSAL-02-4, February 19, 2002
- c. NSAL-03-09, September 22, 2003
- d. NSAL-11-5, Westinghouse LOCA Mass and Energy Release Calculation Rev. 16
RNP-I/INST-1070 Revision 16 Page 10 of 105 Issues, July 25, 2011 4.7.13 Westinghouse letter PGN-02-59 Rev. 1, dated August 7, 2002 4.7.14 DBD/R87038/SD06, DBD for the Reactor and Safeguards Protection System, Revision 12 4.7.15 EC 47208, Replacement of RTGB Recorders, Revision 16 4.7.16 EC 80767, Correct LOCA Containment Analysis Errors, Rev. 0 4.7.17 EC 59047 Steam Generator Level Instrument Uncertainty, Revision 1 4.7.18 WCAP-16115-P, Steam Generator Level Uncertainties Program (See EC 59047 Attachment A) 4.7.19 SG-85-04-21, Westinghouse Steam Generator Thermal-Hydraulic Report 4.7.20 DBD/R87038/SD36, Rev. 15, Post-Accident HVAC Systems 4.7.21 UFSAR Section 7.5.2.1, Revision 26 4.7.22 EC 97661, Robinson Nuclear Plant Instrument Drift Analysis Methodology in Support of 24 Month Surveillance Interval, Revision 1 4.7.23 NUS Instruments Long Term Drift Test for NUS Modules, Final Report Executive Summary, dated October 26, 2001 (Attachment F) 4.7.24 Email form NUS Confirming Similarity of NUS Isolator Modules, dated, January 15, 2002 (Attachment G) 4.7.25 EC 415220 Revision 1, R2C33 Safety Analysis Site Implementation. 4.7.26 EC 420027, Implement SG High Level Feedwater Regulating Valve Interlock. Rev. 16
RNP-I/INST-1070 Revision 14 Page 11 of 105 5.0 INPUTS AND ASSUMPTIONS 5.1 The accuracy of a typical test resistor is on the order of +/- 0.01%. Therefore, the test resistors used during calibration are assumed to have a negligible impact on the overall uncertainty calculation. This is in accordance with the methodology described within Reference 4.6.6. 5.2 Per Reference 4.7.11 (a) and (b), the maximum Containment temperature following an accident is 280°F. Per Reference 4.7.16, the maximum Containment temperature by analysis following an accident is 340°F, which occurs within the first 60 seconds of the transient. The temperature then quickly falls below 280°F. Since the operator would not reach EOP steps that contain adverse setpoints is that short of time (i.e. less than 100 seconds), for EOP setpoint use only, the maximum containment temperature used to compute accident reference leg density effects is 280°F. Per Reference 4.1.9, the minimum Containment temperature during normal operation is 88°F and is assumed to be the minimum Containment temperature following an accident. Therefore, the maximum and minimum Containment temperatures used to compute accident reference leg density effects are 340°F and 88°F respectively for non-EOP applications and 280°F and 88°F respectively for EOP applications. In the event of a single feedwater line break, per WCAP-16115P, the maximum containment temperature is 225°F, which will be used to determine the accident reference leg effects. 5.3 Per Reference 4.1.13, the transmitter reference leg is connected to a condensate pot that is connected to the upper Steam Generator instrument tap. Due to the short piping run from the upper instrument tap to the condensate pot, the change in height from the instrument tap to the condensate pot is assumed to be negligible. 5.4 Per Reference 4.1.13, a portion of the transmitter reference leg is located inside the Steam Generator shield wall. The temperature inside the shield wall is greater than the ambient temperature inside Containment. Per Reference 4.2.3, a maximum Containment temperature of 130°F is used in the Containment analysis. For conservatism, the temperature inside the shield wall is assumed to be 140°F and is used to compute normal reference leg density effects. Per Reference 4.1.9, the minimum temperature inside Containment is 88°F. Therefore, a minimum temperature of 88°F is used to compute normal reference leg density effects. 5.5 Per Reference 4.6.6, reference accuracy typically includes the effects of linearity, hysteresis, and repeatability. The indicator reference accuracy is stated within Reference 4.2.2. The value is given as 2% full scale for a DC meter. Repeatability is listed separately and is stated as being in accordance with ANSI C39.1. Per C39.1 Plate 5 for a Direct Current Application, Edgewise instrument, repeatability is only applicable to the microammeter option. As this is not a microammeter application, the repeatability is
RNP-I/INST-1070 Revision 14 Page 12 of 105 taken to be included within the reference accuracy term. The reference accuracy will be taken to include the effects of linearity, hysteresis, and repeatability in accordance with Reference 4.6.6. 5.6 Per References 4.5.2 through 4.5.10, the I/V module is calibrated as part of a string. Per Reference 4.4.1, the I/V module is a resistor. Resistors typically experience negligible drift. Therefore, any resistor drift throughout the fuel cycle is negligible and is accounted for during the string calibration. 5.7 Per Reference 4.2.3, the maximum containment temperature assumed within the containment analysis is 130ºF. Technical Specification 3.6.5 limits containment average air temperature to less than or equal to 120ºF. For the purpose of this calculation, 130ºF will be used as the upper limit of containment temperature. Per review of OSI PI data for Tag CVT0001 Volume Weighted Ave CV Air Temp, it can be seen that the containment temperature trends greater than 60ºF. For the purpose of this calculation, 50ºF will be used as the lower limit for containment temperature. 5.8 The Hagan Room normal operating temperature is 50°F to 82ºF. The low limit of 50ºF is chosen as it is the more conservative value when comparing the 50ºF alarm setpoint [from Reference 4.6.3] for TS-A42 (HVA-2 Lo Temp Switch) and the 55ºF heater setpoint [from Reference 4.6.4] for TS-A40 (Temperature Switch for EDH-4). The basis for the 82ºF is the Hot Operations Log (TIN R0041). The hot operations log directs the installation of supplemental cooling when Hagan Room temperatures reach 78ºF, and the initiation of an NCR and an operability review when Hagan Room temperatures reach 82ºF. Per Reference 4.6.1 Section 9.4.3, the racks may experience an additional internal 10°F heat rise during operation. Therefore, a change in temperature of 42°F (23.33°C) is used to compute the normal temperature effect associated with rack components in setpoint and normal indication loops. 82°F + 10°F 50°F = 42°F The Hagan Room accident operating temperature is 50ºF to 120ºF. The low limit basis is as noted above. In order to bound a postulated loss of HVAC scenario (as can be induced by a Loss of Offsite Power), a Heatup analysis of the Hagan Room was completed by Reference 4.2.6. The maximum room temperature at the equipment elevation is 110ºF when the SPP-045 controls are applied. For conservatism, the high limit is taken to be 120ºF. As EOP-ECA-0.0 (Reference 4.6.5) requires opening all cabinet doors in the Hagan Room within 30 minutes, an internal cabinet heat rise is not specifically evaluated. Therefore, a change in temperature of 70°F (38.89°C) is used to compute the accident temperature effect associated with rack components in EOP indicator loops. 5.9 The Westinghouse 3110552-000 Computer Signal Conditioner is a high precision
RNP-I/INST-1070 Revision 14 Page 13 of 105 resistor. Based on the high accuracy of the resistor, the resistor has a negligible impact on the overall loop uncertainty computation. 5.10 Per Reference 4.7.3, Table 18, the lowest set pressure of the Main Steam Safety Valves is 1100 psia. Therefore, 1100 psia is the maximum pressure used to compute accident process measurement effects. Following a main steam line break, the Steam Generator will rapidly blow down to ambient Containment pressure. Therefore, a minimum Steam Generator pressure of 15 psia is used to compute accident process measurement effects. Note that Table 18 of Reference 4.7.3 provides the set pressure of the Main Steam Safety Valves in terms of psig. 5.11 Deleted 5.12 Per Reference 4.7.9, Steam Generator pressure is approximately 800 psia at 100% load and 1020 psia at 0% load. Therefore, the minimum and maximum pressure used to compute normal process measurement effects are 800 psia and 1020 psia respectively. 5.13 Per UFSAR Chapter 15, the High Steam Generator Level valve interlock is not credited in the safety analysis. This setpoint serves to protect against the Steam Generator becoming water solid and feedwater entering the main steam lines. NSAL-02-4 (Reference 4.7.12) identifies a previously unconsidered source of uncertainty. Due to the void content of the two-phase mixture above the mid-deck plate, the steam generator water level instrument channel(s) will not indicate water level as accurately as presumed when level is above the mid-deck plate. As a result, a high-high level trip (actuation) may not occur, even though the two-phase mixture level may actually be above the upper level tap. NSAL-02-4 provides a means of determining maximum reliable indicated level (MRIL) for steam generators and provides technical input that quantifies the void fraction above mid-deck plate for H. B. Robinsons steam generators at 11%. Per NSAL-02-4, MRIL is determined as follows: MRIL = 100% - (100% Level - Mid Deck Level) (Void Fraction) 100% Level Span = 143 inches (Reference 4.1.15) 100% Level Span with elongation correction = 143.5 inches (Section 9.1) Distance from Tube Sheet to Lower Tap = 385.625 inches (Reference 4.7.9) Distance from Tube Sheet to Mid Deck Plate = 500.0675 inches (Ref. 4.7.9) Void Fraction = 11% (Reference 4.7.12) Distance from Lower Tap to Mid Deck (MD) = (500.0675 - 385.625) inches
= 114.4425 inches
RNP-I/INST-1070 Revision 14 Page 14 of 105 Thus, MD as a % of Narrow Range Span is: MD = =
5. 143 4425 114 79.751% of Span Therefore: MRIL = 100% (100% MD) (11%) MRIL = 97.773 % Level This MRIL is conservatively rounded to 97.77% Narrow Range Level. Since this is the upper limit for reliable level indication, the Analytic Limit for the High Level Valve Interlock addressed in this calculation is conservatively chosen at 97% span (Reference 4.2.10). 5.14 Per Reference 4.7.20, the Control Room normal operating temperature is 70ºF to 77ºF dry bulb, inclusive under all modes of operation. Per Reference 4.7.21, the normal ambient design temperature for Control Room located equipment is 75ºF (plus or minus 10ºF), which can also be stated as a temperature range of 65 ºF to 85 ºF. Per Reference 4.7.2, the Control Room Emergency Air Temperature Control (CREATC) maintains the Control Room temperature less than or equal to 85ºF. Therefore, a maximum change in temperature of 20ºF (11.1ºC) is used to compute the indicator and recorder temperature effect. 5.15 The High Steam Generator Level alarm serves to warn the operator that Steam Generator Level is approaching the High Steam Generator Level valve interlock setpoint. Therefore, the limit for this setpoint is set to the High Steam Generator Level valve interlock setpoint of 75% Span (References 4.5.2 through 4.5.10, and 4.7.3, Table 2). 5.16 The Low Steam Generator Level alarm serves to warn the operator that Steam Generator Level is approaching the Low Steam Generator Level Reactor Trip setpoint. Therefore, the limit for this setpoint is set to the Low Steam Generator Level Reactor Trip setpoint of 30% Span (Reference 4.7.2). 5.17 Deleted 5.18 Reference 4.7.12.a identifies a bias effect due to a differential pressure at the moisture separator mid-deck. For the purposes of this calculation, this bias shall be called mid-deck differential pressure bias, or MDDPb. Documented evaluations in Reference 4.7.12.a assert that this MDDPb would be negative (conservative) for a Feedwater Line Break accident and positive (non-conservative) for Loss of Offsite Power and Loss of Normal Feedwater Accidents. The steam flow to be considered in
RNP-I/INST-1070 Revision 14 Page 15 of 105 determining the P across the Moisture Separator Mid Deck Plate was increased from 100% to 112% by WCAP 16115P. Per Table 6.1 of WCAP 16115P the value of this P increased from 0.17 to 0.19psi This value can be converted to units of % Span using the specific gravity of water, 0.0160454 ft3 / lbm, and the transmitter calibrated span of 108 inches (Section 6.4.1) as follows: =
= ft in 12 ft in 144 pound ft 0.0160454 in pounds 0.19 MDDPb 2 2 3 2 5.27 inches =
= inches 108 Span 100% inches 5.27 MDDPb 4.88% Span For normal (non transient operational conditions, the Mid Deck Plate pressure drop remains as follows: =
= ft in 12 ft in 144 pound ft 0.0160454 in pounds 0.17 MDDPb 2 2 3 2 4.71 inches =
= inches 108 Span 100% inches 4.71 MDDPb 4.36% Span 5.19 Technical information included in Reference 4.4.5 shows the recorder manufacturer does not specify a time dependent drift uncertainty for these digital devices. It is therefore assumed that such drift is negligible and is included within the Reference Accuracy (RA) and Temperature Effect (TE) specification. 5.20 The resolution for a 6 Vdc range digital recorder is 1 mVdc per Reference 4.4.5. For conservatism, a 4 volt range will be used since the input to the recorder is 1 to 5 Vdc. 5.21 Feedwater Ring/Feedwater Ring Supports A combination of recirculation flow and feedwater flows downward past the feedwater ring and the feedwater ring supports. This results in a P across these components. In the Westinghouse Model 44F Steam Generator, the Feedwater Ring and Feedwater Ring Supports are between the Narrow Range Level Taps. As a result of this location the P sensed by the narrow range level instrumentation is impacted. The value for this effect given by WCAP 16115P is 0.006 psi. The instrumentation is
RNP-I/INST-1070 Revision 14 Page 16 of 105 calibrated to inches of water. The instrumentation system measures the level as inches of water and provides an output in % level as a % of the level indication span. For the narrow range level indication the span is 108 inches. The pressure may be converted to inches of H2O (at 500°F, 900 psia) as follows: 1 inch water = 49.03889 lb/ft3 X (1/12 ft/in)3 X 1 in H2O =.02838 psi ( ) ER INCHES_WAT PSI PSI WATER 0.211 0.006 0.02838 1" =
SPAN = 108 INCHES FEED RING%SPAN = 195 .0 100 108 211 .0 =
% Span In the case of the High functions, WCAP 16115P recommends an additional error for operation at less than 100% power. Per table 5-1 in WCAP 16115P, the additional error for the feedring P is 0.007 psi (total) for 44F with three primary separators (Tech Manual 728-208-63, sect. 1.1). Using the above methodology, this results in the following: (1/0.02838) * (0.007) = 0.247 water FEED RING<100% SPAN = 0.23% Span Based on the dimensions provided in HBR2-10750, HBR2-10731, and HBR2-10736, the Feedwater Nozzle is located at 24% span. Since the PMA effects are a result of a submerged feedring, only those alarms and control functions that occur at a level 24% narrow range indicated span will be impacted. The following are the alarm and trip location in % span. Low-Low Level Reactor Trip; 16% span Low-Low Level Alarm: 35% span Low Level Alarm: 35% span High Level Alarm: 60% span (increasing level setpoint) High Level Valve Interlock: 75% span (increasing level setpoint) When the actual level in the Steam Generator is below the feedwater ring and feedwater ring supports this PME = 0. When above the feedwater ring and feedwater ring supports the indicated level will be less than actual level. Therefore, this term results in a negative bias which will only be applied to increasing level setpoints above the feedring elevation of 24%.
RNP-I/INST-1070 Revision 14 Page 17 of 105 5.22 Per Reference 4.2.5 for Setpoint M.13, normal containment EOP setpoint values are used up to an assumed containment temperature of 190°F. This impacts the normal containment transmitter temperature effect as well as the PME values. This impacts only EOP setpoint calculations and should not be used for RPS/EFSAS setpoints. 5.23 Setpoint values in the EOPs are always rounded in the conservative direction to a readable value. Therefore, the inclusion of a readability error in the instrument uncertainty calculations for the indicators and recorder are not necessary for EOP setpoint applications. 5.24 Per Reference 4.4.1 in Section 9.5.1, the Westinghouse 3110554-000 I/V is a high precision 250 resistor with an accuracy of +/ 0.01%. Therefore, the Current to Voltage module is taken to have a negligible impact on the overall uncertainty calculation. This is in accordance with the methodology described within Reference 4.6.1. 5.25 For the Cases evaluated in Section 6.0, the Specific Gravity was calculated according to Procedure EGR-NGGC-0153 Engineering Instrument Setpoints Section 9.3.1.(Reference 4.6.1), using the specific volume from the ASME Steam Tables (Reference 4.7.5) in the following equation: Specific Gravity = specific volume of water @ 68ºF / specific volume of fluid Specific Gravity = 0.016046 / Vf or Vg where Vf = specific volume of fluid Vg = specific volume of steam 5.26 As part of the 24 month fuel cycle project this project, a drift analysis was performed on most of the Technical Specification related transmitters to provide new drift values based on historical numbers. A drift analysis was not required to be performed on the portions of the loop that are tested by a quarterly (92 days) Channel Operability Test (COT) that verifies the rack tolerances. Rather than unnecessarily increase the value of component drift to reflect the longer calibration time, this calculation will take credit for the performance of the COT, which includes adjustments, as necessary, for the tested setpoints. The value for drift over an 18 month period is still conservative, and will not be changed. 5.27 An effect of the Drift Studies performed per EC 97661 (Reference 4.7.22) is that in addition to the component drift (DR), the Analyzed Drift (AD) value includes several sources of uncertainty, including the Reference Accuracy (RA) and Measuring and Test Equipment error (MTE). The As-Found/As-Left technique does not and cannot
RNP-I/INST-1070 Revision 14 Page 18 of 105 separate these factors that combine into the AD. Therefore, where the AD exceeds the DR, the results of the drift study may replace the RA, MTE, and DR factors as a single value for determination of the Total Device Uncertainty (TDU) and As-Found Tolerance (AFT). Where the DR exceeds the AD, and if desired to reduce conservatism, the AD may replace the RA, MTE, and DR factors in determination of the TDU and the AFT values. This is in accordance with Reference 4.6.6, which recommends the performance of a drift analysis, but does not specifically call out combining these terms. 5.28 As part of the 24 month fuel cycle project, the nominal calibration interval is being extended to 24 months with a maximum of 30 months (24 months + 25%).
RNP-I/INST-1070 Revision 14 Page 19 of 105 6.0 CALCULATION OF UNCERTAINTY CONTRIBUTORS 6.1 ACCIDENT EFFECTS (AE) Per Reference 4.6.2, the indication / recording functions provided by each loop are required post accident, so accident effects are computed for the indication / recording functions. Per UFSAR Chapter 15, the Low Low Steam Generator Level Reactor Trip is credited in the safety analysis. Per Reference 4.7.2, this trip serves to prevent the loss of the Steam Generator as a heat sink as the result of a loss of power to the station auxiliaries, loss of normal feedwater, and a feedwater line break. A feedwater line break inside containment will create a harsh Containment environment, but not a high radiation environment. Therefore, accident temperature effects are included in the total loop uncertainties for this trip function, but accident radiation effects are not. Per EC 59047 additional effects are evaluated as applicable to the accident condition; Mid Deck Plate P, and Downcomer Subcooling. The Low Low, and High Steam Generator Level alarms serve to warn the operator that Steam Generator Level is outside the normal control band and are not used for accident mitigation. Therefore, only normal uncertainties are computed for the alarm. The High Steam Generator Level valve interlock serves to close the feedwater control valves before the Steam Generator is completely full and feedwater enters the main steam lines. This function serves to prevent turbine damage. Since the main steam lines are not designed to contain water, this function also serves to prevent a possible main steam line break accident. The valve interlock serves as an equipment protection function not a safety function. Therefore, accident effects are not included in the total loop uncertainties for the valve interlock. Seismic uncertainties are included in the total loop uncertainties for this function. The uncertainty at the input to AMSAC is computed for normal environmental conditions only. AMSAC is a non-safety system that is not required to mitigate a design basis event. Its function is to terminate anticipated transients where a loss of the Steam Generator as a heat sink is possible, and a Reactor Trip is not generated by Reactor Protection System. 6.1.1 Accident Temperature Effect (ATE) Per EDB, the transmitter in each loop is a Rosemount 3154ND2R2F1E7. Per Reference 4.4.3, the transmitter Accident Temperature Effect (ATExmtr) is given as +/- 1% Upper Range Limit plus 1% Span. The Upper Range Limit (URL) of a range code 2 transmitter is 250 inwc. Per Section 9.1, the span of each transmitter is 108 inwc. Therefore, the ATExmtr associated with each transmitter is computed as follows:
RNP-I/INST-1070 Revision 14 Page 20 of 105 ATExmtr = +/- {(1.0%) 250 108 + 1.0% } ATExmtr = +/- 3.32% Span 6.1.2 Accident Pressure Effect (APE) The transmitter in each loop is a differential pressure transmitter. Therefore, there are no Accident Pressure Effects. 6.1.3 Accident Radiation Effect (ARE) Per EDB, the transmitter in each loop is a Rosemount 3154ND2R2F1E7. Per Reference 4.4.3, the transmitter Accident Radiation Effect (ARExmtr) is given as +/- 0.3% Upper Range Limit plus 1.00% Span. The Upper Range limit (URL) of a range code 2 transmitter is 250 inwc. Per Section 9.1, the span of each transmitter is 108 inwc. Therefore, the ARExmtr associated with each transmitter is computed as follows: ARExmtr = +/-{(0.3%) 250 108 + 1.0% } ARExmtr = +/- 1.69% Span 6.2 SEISMIC EFFECT (SE) Per EDB, the transmitter in each loop is a Rosemount 3154ND2R2F1E7. Per Reference 4.4.3, the seismic effect associated with the transmitter is +/- 0.50% Upper Range Limit (URL), and the URL of a range code 2 transmitter is 250 inwc. Per Section 9.1 of this calculation, the calibrated span of each loop is 108 inwc. Therefore, SExmtr = +/- 0.50% ( 250 108 )= +/- 1.16% Span The SE is bounded by the ATE computed in Section 6.1.1. Therefore, the SE is not included in the uncertainty analysis for the indication, recording, alarm functions, or Low Low Steam Generator Level Trip function. Since the Low Steam Generator Reactor Trip and the High Level Valve Interlock do not include accident effects, the seismic effect is included in the uncertainties for this function. 6.3 INSULATION RESISTANCE ERROR (IR)
RNP-I/INST-1070 Revision 14 Page 21 of 105 Per RNP-I/EQ-1175, the Insulation Resistance (IR) effect associated with the loop signal cabling inside Containment is a worst case bias of +2.2072% Span for LT-474. Therefore, IR = +2.21% Span 6.4 PROCESS MEASUREMENT ERROR (PME) 6.4.1 Process Measurement Error - Normal Environment Density Effects Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to compute the process measurement effects which result from changes in reference leg fill fluid density variations and process density variations from those assumed for scaling: PME(inwc) = ( ) C RN SN WN P SG H SG h H SG h
+
- where, h = height of fluid (inches)
H = height of measured level span = 143.5 inches (Section 9.1) SGWN = specific gravity of fluid during operation SGSN = specific gravity of steam during operation SGRN = specific gravity of reference leg fill fluid during operation PC = differential pressure associated with a particular level measurement at conditions assumed for scaling. P Span = 108 inwc (Section 9.1) Therefore, PME(% Span) = Span 100% Span P ) inwc ( PME
Per Section 9.1, the following conditions are assumed for loop scaling: SGWC = 0.787341 @ 900 psia, 500°F SGSC = 0.032034 @ 900 psia, saturated SGRC = 0.992946 @ 900 psia, 120°F, compressed
RNP-I/INST-1070 Revision 14 Page 22 of 105 The differential pressure associated with a particular level measurement is computed with the following equation: PC = ( ) RC SG H
+ SC WC SG h H SG h Differential pressures are computed for the specific points of interest across the level span: The process measurement effect accounts for variations in process pressure and reference leg temperature. The following process conditions are obtained from Design Inputs 5.4 and 5.12. Normal Conditions 800 psia to 1020 psia (Steam Generator pressure) 88°F to 140°F (Reference leg temperature) A total of four possible conditions are considered for normal operation: Case I Reference Leg = 88°F, 1020 psia Process Pressure = 1020 psia, saturated Case II Reference Leg = 140°F, 1020 psia Process Pressure = 1020 psia, saturated Case III Reference Leg = 88°F, 800 psia Process Pressure = 800 psia, saturated Case IV Reference Leg = 140°F, 800 psia Process Pressure = 800 psia, saturated Fluid Height (% Span) Fluid Height (in) Calibrated PC (inwc) 0.00% 0.00 -138 16.00% 22.96 -121 30.00% 43.05 -105 50.00% 71.75 -84 75.00% 107.63 -57 100.00% 143.50 -30
RNP-I/INST-1070 Revision 14 Page 23 of 105 Case I SGRN = 1.000125 @ 88°F, 1020 psia SGSN = 0.036786 @ 1020 psia saturated SGWN = 0.740813 @ 1020 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RN SN WN N SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc norPME C N
= ( ) ( ) Span 100 Span P inwc norPME Span norPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% Span) Fluid Height (in) Actual PN (inwc) Calibrated PC (inwc) norPME (inwc) norPME (% Span) 0.00% 0 -138.24 -138 -0.24 -0.22% 16.00% 22.96 -122.07 -121 -1.07 -1.00% 30.00% 43.05 -107.93 -105 -2.93 -2.71% 50.00% 71.75 -87.73 -84 -3.73 -3.45% 75.00% 107.63 -62.47 -57 -5.47 -5.06% 100.00% 143.50 -37.21 -30 -7.21 -6.68%
RNP-I/INST-1070 Revision 14 Page 24 of 105 Case II SGRN = 0.988054 @ 140°F, 1020 psia SGSN = 0.036786 @ 1020 psia saturated SGWN = 0.740813 @ 1020 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RN SN WN N SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc norPME C N
= ( ) ( ) Span 100 Span P inwc norPME Span norPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% Span) Fluid Height (in) Actual PN (inwc) Calibrated PC (inwc) norPME (inwc) norPME (% Span) 0.00% 0.00 -136.51 -138 1.493 1.38% 16.00% 22.96 -120.34 -121 0.658 0.61% 30.00% 43.05 -106.20 -105 -1.199 -1.11% 50.00% 71.75 -85.99 -84 -1.993 -1.85% 75.00% 107.63 -60.74 -57 -3.736 -3.46% 100.00% 143.50 -35.48 -30 -5.479 -5.07%
RNP-I/INST-1070 Revision 14 Page 25 of 105 Case III SGRN = 0.999502 @ 88°F, 800 psia SGSN = 0.028202 @ 800 psia saturated SGWN = 0.768855 @ 800 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RN SN WN N SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc norPME C N
= ( ) ( ) Span 100 Span P inwc norPME Span norPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% Span) Fluid Height (in) Actual PN (inwc) Calibrated PC (inwc) norPME (inwc) norPME (% Span) 0.00% 0.00 -139.38 -138 -1.38 -1.28% 16.00% 22.96 -122.38 -121 -1.38 -1.27% 30.00% 43.05 -107.50 -105 -2.50 -2.31% 50.00% 71.75 -86.24 -84 -2.24 -2.07% 75.00% 107.63 -59.67 -57 -2.67 -2.47% 100.00% 143.50 -33.10 -30 -3.10 -2.87%
RNP-I/INST-1070 Revision 14 Page 26 of 105 Case IV SGRN = 0.987446 @ 140°F, 800 psia SGSN = 0.028202 @ 800 psia saturated SGWN = 0.768855 @ 800 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RN SN WN N SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc norPME C N
= ( ) ( ) Span 100 Span P inwc norPME Span norPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% Span) Fluid Height (in) Actual PN (inwc) Calibrated PC (inwc) norPME (inwc) norPME (% Span) 0.00% 0.00 -137.65 -138 0.35 0.32% 16.00% 22.96 -120.65 -121 0.35 0.33% 30.00% 43.05 -105.77 -105 -0.77 -0.71% 50.00% 71.75 -84.51 -84 -0.51 -0.47% 75.00% 107.63 -57.94 -57 -0.94 -0.87% 100.00% 143.50 -31.37 -30 -1.37 -1.27%
RNP-I/INST-1070 Revision 14 Page 27 of 105 The following table presents the maximum positive and negative process measurement effects computed above for Cases I through IV. Fluid Velocity Effects Per Reference 4.7.9, the Steam Generators are model 44F. Per Reference 4.7.10, the fluid flow past the lower tap decreases the differential pressure across the transmitter. Reference 4.7.13 states that this bias uncertainty is bounded by -7.10% Span. Therefore, the following Fluid Velocity Effect (FVE) bias is introduced into the level measurement: FVE = 7.10% Span Downcomer Subcooling Effects (Normal Conditions) Per Reference 4.7.9, the Steam Generators are model 44F. Per EC 59047, the subcooling of the fluid in the downcomer region in conjunction with a saturated mixture around the U-tubes introduces an additional bias into the level measurement. Therefore, the following Downcomer Subcooling Effect (DSE) bias is introduced into the level measurement: DSE = 0.45% Span This PME is only applicable for steam generator levels below a level where downcomer subcooling can occur. Water draining from the moisture seperators will be at saturation. Only water below the feedring can realistically be at a subcooled temperature. Since the feedring is located at 24% level, only the Steam Generator Low Low Trip (16%) is affected. Feedwater Ring )P (FRE) from section 5.21 FRE = 0.23% This error is only applicable above the level of the feed ring (~24%) for increasing level Fluid Height (% Span) Fluid Height (in) Positive norPME (% Span) Negative norPME (% Span) 0.00% 0.00 1.38% -1.28% 16.00% 22.96 0.61% -1.27% 30.00% 43.05 N/A -2.71% 50.00% 71.75 N/A -3.45% 75.00% 107.63 N/A -5.06% 100.00% 143.50 N/A -6.68%
RNP-I/INST-1070 Revision 14 Page 28 of 105 setpoints. Steam Carryunder in the Downcomer Per WCAP 16115P, Table 3.3.3-1, the calculated value of the effect caused by Steam Carryunder in the Downcomer region of the Steam Generator is small enough to be considered negligible. Therefore UCARRYUNDER = 0% Span This effect deals with non-recoverable fluid pressure losses due to Steam Carryunder. This effect should not be confused with Downcomer Subcooling fluid temperature effects discussed above. Summary The following table presents the total positive and negative process measurement effects with the FVE, DSE, and FRE biases added as appropriate: Normal PME Fluid Height (% Span) Fluid Height (in) Positive norPME (% Span) Negative norPME (% Span) 0.00% 0.00 1.83 -8.38 16.00% 22.96 1.06 -8.37 30.00% 43.05 NA -9.81 50.00% 71.75 NA -10.55 75.00% 107.63 NA -12.39 100.00% 143.50 NA -14.01
RNP-I/INST-1070 Revision 14 Page 29 of 105 6.4.2 Process Measurement Error - Accident Environment Density Effects Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to compute the process measurement effects which result from changes in reference leg fill fluid density variations and process density variations from those assumed for scaling: PME(inwc) = ( ) C RN SN WN P SG H SG h H SG h
+
- where, h = height of fluid (inches)
H = height of measured level span = 143.5 inches (Section 9.1) SGWN = specific gravity of fluid during operation SGSN = specific gravity of steam during operation SGRN = specific gravity of reference leg fill fluid during operation PC = differential pressure associated with a particular level measurement at conditions assumed for scaling. P Span = 108 inwc (Section 9.1) Therefore, PME(% Span) = Span 100% Span P ) inwc ( PME
Per Section 9.1, the following conditions are assumed for loop scaling: SGWC = 0.787341 @ 900 psia, 500°F SGSC = 0.032034 @ 900 psia, saturated SGRC = 0.992946 @ 900 psia, 120°F, compressed
RNP-I/INST-1070 Revision 14 Page 30 of 105 The differential pressure associated with a particular level measurement is computed with the following equation: PC = ( ) RC SC WC SG H SG h H SG h
+ Differential pressures are computed for the specific points of interest across the level span: The process measurement effect accounts for variations in process pressure and reference leg temperature. The following process conditions are obtained from Design Inputs 5.2 and 5.10. Accident Conditions 15 psia to 1100 psia (Steam Generator pressure) 88°F to 340°F (Reference leg temperature) A total of four possible conditions are considered for accident operation: Case I Reference Leg = 88°F, 15 psia Process Pressure = 15 psia, saturated Case II Reference Leg = 15 psia, saturated Process Pressure = 15 psia, saturated Case III Reference Leg = 88°F, 1100 psia Process Pressure = 1100 psia, saturated Case IV Reference Leg = 340°F, 1100 psia Process Pressure = 1100 psia, saturated Fluid Height (% Span) Fluid Height (in) Calibrated PC (inwc) 0.00% 0.00 -138 16.00% 22.96 -121 30.00% 43.05 -105 50.00% 71.75 -84 75.00% 107.63 -57 100.00% 143.50 -30
RNP-I/INST-1070 Revision 14 Page 31 of 105 Case I SGRA = 0.997018 @ 88°F, 15 psia SGSA = 0.000610 @ 15 psia saturated SGWA = 0.959345 @ 15 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RA SA WA A SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc accPME C A
= ( ) ( ) Span 100 Span P inwc accPME Span accPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% Span) Fluid Height (in) Actual PA (inwc) Calibrated PC (inwc) accPME (inwc) accPME (% Span) 0.00% 0.00 -142.98 -138 -4.98 -4.62% 16.00% 22.96 -120.97 -121 0.03 0.03% 30.00% 43.05 -101.71 -105 3.29 3.05% 50.00% 71.75 -74.20 -84 9.80 9.08% 75.00% 107.63 -39.80 -57 17.20 15.93% 100.00% 143.50 -5.41 -30 24.59 22.77%
RNP-I/INST-1070 Revision 14 Page 32 of 105 Case II SGRA = 0.959345 @ 15 psia, saturated SGSA = 0.000610 @ 15 psia saturated SGWA = 0.959345 @ 15 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RA SA WA A SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc accPME C A
= ( ) ( ) Span 100 Span P inwc accPME Span accPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% Span) Fluid Height (in) Actual PA (inwc) Calibrated PC (inwc) accPME (inwc) accPME (% Span) 0.00% 0.00 -137.58 -138 0.42 0.39% 16.00% 22.96 -115.57 -121 5.43 5.03% 30.00% 43.05 -96.30 -105 8.70 8.05% 50.00% 71.75 -68.79 -84 15.21 14.08% 75.00% 107.63 -34.39 -57 22.61 20.93% 100.00% 143.50 0.00 -30 30.00 27.78%
RNP-I/INST-1070 Revision 14 Page 33 of 105 Case III SGRA = 1.000125 @ 88°F, 1100 psia SGSA = 0.040057 @ 1100 psia saturated SGWA = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RA SA WA A SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc accPME C A
= ( ) ( ) Span 100 Span P inwc accPME Span accPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% Span) Fluid Height (in) Actual PA (inwc) Calibrated PC (inwc) accPME (inwc) accPME (% Span) 0.00% 0.00 -137.77 -138 0.23 0.21% 16.00% 22.96 -121.91 -121 -0.91 -0.84% 30.00% 43.05 -108.02 -105 -3.02 -2.80% 50.00% 71.75 -88.19 -84 -4.19 -3.88% 75.00% 107.63 -63.40 -57 -6.40 -5.93% 100.00% 143.50 -38.62 -30 -8.62 -7.98%
RNP-I/INST-1070 Revision 14 Page 34 of 105 Case IV SGRA = 0.901967 @ 340°F, 1100 psia SGSA = 0.040057 @ 1100 psia saturated SGWA = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RA SA WA A SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc accPME C A
= ( ) ( ) Span 100 Span P inwc accPME Span accPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% span) Fluid Height h (in) Actual PA (inwc) Calibrated PC (inwc) accPME (inwc) accPME (% span) 0.00% 0.00 -123.68 -138 14.32 13.26 16.00% 22.96 -107.82 -121 13.18 12.20 30.00% 43.05 -93.94 -105 11.06 10.24 50.00% 71.75 -74.11 -84 9.89 9.16 75.00% 107.63 -49.32 -57 7.68 7.11 100.00% 143.50 -24.53 -30 5.47 5.06
RNP-I/INST-1070 Revision 14 Page 35 of 105 The following table presents the maximum positive and negative process measurement effects computed above for Cases I through IV. Fluid Height (% span) Fluid Height h (in) Positive accPME (% span) CASE # Negative accPME (% span) CASE # 0.00% 0 13.26% IV -4.62% I 16.00% 22.96 12.20% IV -0.84% III 30.00% 43.05 10.24% IV -2.80% III 50.00% 71.75 14.08% II -3.88% III 75.00% 107.63 20.93% II -5.93% III 100.00% 143.50 27.78% II -7.98% III Specific Conditions during a Feedwater Break Accident In order to maintain adequate margin of the Low Low Trip Setpoint, the specific conditions of a feed water line break need to be addressed. Per WCAP-16115P, the maximum temperature that the reference legs will see is 225°F. Using the above methodology and the following values: SGRA = 0.958283 @ 225°F, 1020 psia SGSA = 0.036795 @ 1020 psia saturated SGWA = 0.740776 @ 1020 psia saturated Then, the accPME at 0% level (condition of interest) is: Fluid Height (% Span) Fluid Height (in) Actual Pa (inwc) Calibrated Pc (inwc) accPME (inwc) accPME (% Span) 0.00 0 -132.23 -138 5.77 5.34 See EC 59047 for additional discussion. Fluid Velocity Effects Per Reference 4.7.9, the Steam Generators are model 44F. Per Reference 4.7.10, the fluid flow past the lower tap decreases the differential pressure across the transmitter. Reference 4.7.13 states that for HBR2, this fluid velocity effect is bounded by -7.10% Span. Therefore, the following Fluid Velocity Effect (FVE) bias is introduced into the level measurement:
RNP-I/INST-1070 Revision 14 Page 36 of 105 FVE = -7.10% Span Downcomer Subcooling Effects (Accident conditions) Per Reference 4.7.9, the Steam Generators are model 44F. Per EC 59047, the subcooling of the fluid in the downcomer region in conjunction with a saturated mixture around the U-tubes introduces an additional bias into the level measurement. Therefore, the following Downcomer Subcooling Effect (DSE) bias is introduced into the level measurement. Downcomer Subcooling is unchanged under accident condition so: DSE = 0.45% Span Feedwater Ring P (FRE) from section 5.21 Feedring Bias is unchanged for accident conditions, From section 5.21 FRE = -0.23% Span Summary The following table presents the total positive and negative process measurement effects with the FVE, FRE, and DSE biases added. Note that the Feedring bias only applies for levels greater than the feedring level of 24%, and that the DSE only applies for levels below the feedring level of 24%. Fluid Height (% span) Fluid Height h (in) Positive accPME (% span) Negative accPME (% span) 0.00% 0 13.71% -11.72% 16.00% 22.96 12.65% -7.94% 30.00% 43.05 10.24% -10.13% 50.00% 71.75 14.08% -11.21% 75.00% 107.63 20.93% -13.26% 100.00% 143.50 27.78% -15.31% Accident PME For a feed water line break, the Positive accPME at the % level of interest reduces to : Fluid Height (% Span) Fluid Height (in) Positive accPME (% Span) Negative accPME (% Span)
RNP-I/INST-1070 Revision 14 Page 37 of 105 6.4.3 Process Measurement Error - Normal Environment for EOP Use As discussed in Design Input 5.22, normal containment setpoint values are used in EOPs up to a containment temperature of 190°F. Therefore, the PME temperature effects are slightly different than the effect calculated in Section 6.4.1. In addition, the SG pressure may range from atmospheric pressure (15 psia) to the lowest SG safety valve setting (1085 psig ) per Design Input 5.10. Density Effects Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to compute the process measurement effects which result from changes in reference leg fill fluid density variations and process density variations from those assumed for scaling: PME(inwc) = ( ) C RN SN WN P SG H SG h H SG h
+
- where, h = height of fluid (inches)
H = height of measured level span = 143.5 inches (Section 9.1) SGWN = specific gravity of fluid during operation SGSN = specific gravity of steam during operation SGRN = specific gravity of reference leg fill fluid during operation PC = differential pressure associated with a particular level measurement at conditions assumed for scaling. P Span = 108 inwc (Section 9.1) Therefore, PME(% Span) = Span 100% Span P ) inwc ( PME
0.00% 0.00 5.79% -11.72%
RNP-I/INST-1070 Revision 14 Page 38 of 105 Per Section 9.1, the following conditions are assumed for loop scaling: SGWC = 0.787341 @ 900 psia, 500°F SGSC = 0.032034 @ 900 psia, saturated SGRC = 0.992946 @ 900 psia, 120°F, compressed The differential pressure associated with a particular level measurement is computed with the following equation: PC = ( ) RC SC WC SG H SG h H SG h
+ Differential pressures are computed for the specific points of interest across the level span: The process measurement effect accounts for variations in process pressure and reference leg temperature. The following process conditions are obtained from Design Inputs 5.4 and 5.12. Normal Conditions 15 psia to 1100 psia (Steam Generator pressure) 88°F to 190°F (Reference leg temperature) A total of four possible conditions are considered for normal containment conditions in the EOP. Note the case numbers are consistent with section 6.4.1 with an e appended. The difference between the cases in Section 6.4.1 and here are the SG pressure assumed for each and the reference leg temperature assumed in cases IIIe and IVe. Fluid Height (% Span) Fluid Height (in) Calibrated PC (inwc) 0.00% 0.00 -138 16.00% 22.96 -121 30.00% 43.05 -105 50.00% 71.75 -84 75.00% 107.63 -57 100.00% 143.50 -30
RNP-I/INST-1070 Revision 14 Page 39 of 105 Case Ie Reference Leg = 88°F, 1100 psia Process Pressure = 1100 psia, saturated Case IIe Reference Leg = 190°F, 1100 psia Process Pressure = 1100 psia, saturated Case IIIe Reference Leg = 88°F, 15 psia Process Pressure = 15 psia, saturated Case IVe Reference Leg = 190°F, 15 psia Process Pressure = 15 psia, saturated Case Ie SGRA = 1.000125 @ 88°F, 1100 psia SGSA = 0.040057 @ 1100 psia saturated SGWA = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RN SN WN N SG H SG h H SG h inwc P Actual
+ =
( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc norPME C N
= ( ) ( ) Span 100 Span P inwc norPME Span norPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% span) Fluid Height (in) Actual dP (inwc) Calibrated dP (inwc) Calculated eopPME (inwc) Calculated eopPME (% span) 0.00% 0.00 -137.77 -137.89 0.12 0.11% 16.00% 22.96 -121.91 -120.55 -1.36 -1.26% 30.00% 43.05 -108.02 -105.37 -2.65 -2.45% 50.00% 71.75 -88.19 -83.70 -4.49 -4.17% 75.00% 107.63 -63.40 -56.60 -6.80 -6.30% 100.00% 143.50 -38.62 -29.50 -9.12 -8.44%
RNP-I/INST-1070 Revision 14 Page 40 of 105 Case IIe SGRN = 0.971896 @ 190°F, 1100 psia SGSN = 0.040057 @ 1100 psia saturated SGWN = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RN SN WN N SG H SG h H SG h inwc P Actual
+ = ( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc norPME C N
= ( ) ( ) Span 100 Span P inwc norPME Span norPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% span) Fluid Height (in) Actual dP (inwc) Calibrated dP (inwc) Calculated eopPME (inwc) Calculated eopPME (% span) 0.00% 0.00 -133.75 -137.89 4.15 3.84% 16.00% 22.96 -117.88 -120.55 2.67 2.47% 30.00% 43.05 -104.00 -105.37 1.38 1.27% 50.00% 71.75 -84.17 -83.70 -0.47 -0.44% 75.00% 107.63 -59.38 -56.60 -2.78 -2.57% 100.00% 143.50 -34.59 -29.50 -5.09 -4.71%
RNP-I/INST-1070 Revision 14 Page 41 of 105 Case IIIe SGRA = 0.997018 @ 88°F, 15 psia SGSA = 0.000610 @ 15 psia saturated SGWA = 0.959345 @ 15 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RA SA WA A SG H SG h H SG h inwc P Actual
+ = ( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc accPME C A
= ( ) ( ) Span 100 Span P inwc accPME Span accPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% span) Fluid Height (in) Actual dP (inwc) Calibrated dP (inwc) Calculated eopPME (inwc) Calculated eopPME (% span) 0.00% 0.00 -142.98 -137.89 -5.09 -4.71% 16.00% 22.96 -120.97 -120.55 -0.42 -0.39% 30.00% 43.05 -101.71 -105.37 3.66 3.39% 50.00% 71.75 -74.20 -83.70 9.50 8.80% 75.00% 107.63 -39.80 -56.60 16.80 15.56% 100.00% 143.50 -5.41 -29.50 24.09 22.31%
RNP-I/INST-1070 Revision 14 Page 42 of 105 Case IVe SGRN = 0.968377 @ 190°F, 15 psia SGSN = 0.000610 @ 15 psia saturated SGWN = 0.959345 @ 15 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RN SN WN N SG H SG h H SG h inwc P Actual
+ = ( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc norPME C N
= ( ) ( ) Span 100 Span P inwc norPME Span norPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% span) Fluid Height (in) Actual dP (inwc) Calibrated dP (inwc) Calculated eopPME (inwc) Calculated eopPME (% span) 0.00% 0.00 -138.87 -137.89 -0.98 -0.91 16.00% 22.96 -116.86 -120.55 3.69 3.41 30.00% 43.05 -97.60 -105.37 7.77 7.20 50.00% 71.75 -70.09 -83.70 13.61 12.60 75.00% 107.63 -35.69 -56.60 20.91 19.36 100.00% 143.50 -1.30 -29.50 28.21 26.12
RNP-I/INST-1070 Revision 14 Page 43 of 105 The following table presents the maximum positive and negative process measurement effects computed above for Cases I through IV. Fluid Height (% span) Fluid Height (in) Positive eopPME (% span) Negative eopPME (% span) 0.00% 0.00 3.84% -4.71% 16.00% 22.96 3.41% -1.26% 30.00% 43.05 7.20% -2.45% 50.00% 71.75 12.60% -4.16% 75.00% 107.63 19.36% -6.30% 100.00% 143.50 26.12% -8.44%
RNP-I/INST-1070 Revision 14 Page 44 of 105 6.4.4 Process Measurement Error - Accident Environment for EOPs Section 6.4.2 determined the accPME assuming maximum and minimum Containment temperatures of 340°F and 88°F respectively. For EOP applications the maximum and minimum Containment temperatures should be 280°F and 88°F respectively. See Section 5.2. Only Case IV in Section 6.4.2 uses the maximum containment temperature. Thus Cases I, II, and III in Section 6.4.2 apply for EOP use. To avoid confusion with the cases presented in Section 6.4.2, the EOP Case IV will include an e after the case number. Case IVe SGRA = 0.933450 @ 280°F, 1100 psia SGSA = 0.040057 @ 1100 psia saturated SGWA = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below: ( ) ( ) RA SA WA A SG H SG h H SG h inwc P Actual
+ = ( ) ( ) ( ) inwc P Calibrated inwc P Actual inwc accPME C A
= ( ) ( ) Span 100% Span P inwc acceopPME Span acceopPME
=
- where, P Span = 108 inwc (Section 9.1)
Calibrated PC is computed above. H = 143.5 inches (Section 9.1) Fluid Height (% span) Fluid Height h (in) Actual PA (inwc) Calibrated PC (inwc) acceopPME (inwc) acceopPME (% span) 0.00% 0.00 -128.20 -138 9.80 9.07 16.00% 22.96 -112.34 -121 8.66 8.02 30.00% 43.05 -98.46 -105 6.54 6.06 50.00% 71.75 -78.62 -84 5.38 4.98 75.00% 107.63 -53.84 -57 3.16 2.93 100.00% 143.50 -29.05 -30 0.95 0.88
RNP-I/INST-1070 Revision 14 Page 45 of 105 The following table presents the maximum positive and negative process measurement effects computed above for Cases I through III in Section 6.4.2 and Case IVe in Section 6.4.4. Fluid Height (% span) Fluid Height h (in) Positive acceopPME (% span) CASE # Negative acceopPME (% span) CASE # 0.00% 0 9.07% IVe -4.62% I 16.00% 22.96 8.02% IVe -0.84% III 30.00% 43.05 8.05% II -2.80% III 50.00% 71.75 14.08% II -3.88% III 75.00% 107.63 20.93% II -5.93% III 100.00% 143.50 27.78% II -7.98% III In addition to the process measurement effect (acceopPME) calculated above, there are three additional process measurement effects that must be considered during accident conditions. Section 6.4.2 determined the process measurement effects due to fluid velocity (FVE -7.10%), feedwater ring P (FRE -0.23%), and downcomer subcooling (DSE +0.45%). Summary The following table presents the total positive and negative process measurement effects with the FVE (-7.10%), FRE (-0.23%), and DSE (+0.45%) biases determined in Section 6.4.2 added. Note that the Feedring bias (FRE) only applies for levels greater than the feedring level of 24%, and that the downcomer subcooling bias (DSE) only applies for levels below the feedring level of 24%. Fluid Height (% span) Fluid Height h (in) Positive acceopPME (% span) Negative acceopPME (% span) 0.00% 0 9.52% -11.72% 16.00% 22.96 8.47% -7.94% 30.00% 43.05 8.05% -10.13% 50.00% 71.75 14.08% -11.21% 75.00% 107.63 20.93% -13.26% 100.00% 143.50 27.78% -15.31% Accident PME for EOP use only
RNP-I/INST-1070 Revision 14 Page 46 of 105 6.5 PRIMARY ELEMENT ERROR (PE) There is no primary element associated with the instrument loops addressed in this calculation. 6.6 Transmitter 6.6.1 Transmitters Unverified Attributes of Reference Accuracy (RAxmtr) Per Reference 4.4.3, the reference accuracy of the transmitter is +/- 0.2% Span and includes the effects of linearity, hysteresis, and repeatability. Per References 4.5.1 and 4.5.11, the transmitter is calibrated to +/- 0.50% Span at nine points (5 up and 4 down). Therefore, the calibration procedure verifies the attributes of linearity and hysteresis but not repeatability. Per Reference 4.6.6, the following equation is utilized to compute the repeatability portion of the transmitter reference accuracy: Repeatability = +/- 3 RA xmtr = +/- 0.2% 3 = +/- 0.12% Span Therefore, RAxmtr = +/- 0.12% Span 6.6.2 Transmitter Calibration Tolerance (CALxmtr) Per Reference 4.5.11, the transmitter is calibrated to +/- 0.50% Span. Therefore, CALxmtr = +/- 0.50% Span _t
RNP-I/INST-1070 Revision 14 Page 47 of 105 6.6.3 Transmitter Drift (DRxmtr) Per Ref 4.4.3, the transmitter drift is given as +/- 0.10% Upper Range Limit (URL) over a time period of thirty months. Per Reference 4.4.3, the URL for a range code 2 transmitter is 250 inwc. Per Section 9.1, the calibrated span of the transmitter is 108 inwc. Therefore, DRxmtr = +/-( 0.1% )= +/-0.10%( 250 108 )= +/- 0.23% Span Based on historical As-Found/As-Left data from calibration records, RNP-I/INST-1212 (Reference 4.2.7) determined a bounding 30 month analyzed drift (AD) value composed of a random 2 value term of +/-1.044% Span, and a negative bias term of 0.227% Span. Since the current drift value of +/-0.28% Span does not bound the random term of the AD value for the current calibration interval or the extended 30 month interval, the AD value will be used in this calculation, therefore, ADxmtr = +/- 1.044% Span ADxmtrBIAS = 0.227% Span 6.6.4 Transmitter M&TE Effect (MTExmtr) A DMM, pressure gauge, and the instrument loop test point resistor are used to calibrate the transmitter. Per Reference 4.6.6, the combined (SRSS) accuracy of all the M&TE used to calibrate the transmitter is better than or equal to the calibration accuracy of the transmitter. For conservatism and flexibility in the choice of test equipment, the MTE term for the transmitter is set equal to the calibration tolerance of the transmitter. MTExmtr = +/- 0.50% Span
RNP-I/INST-1070 Revision 14 Page 48 of 105 6.6.5 Transmitter Temperature Effect (TExmtr) Per Reference 4.4.3, the transmitter temperature effect is given as +/- 0.15% Upper Range Limit + 0.60% Span for a change in temperature of 100°F from the temperature at which the transmitter was calibrated. Per Reference 4.4.3, the Upper Range Limit (URL) for a range code 2 transmitter is 250 inwc, and the calibrated span of each transmitter is 108 inwc (Section 9.1). Per TMM-026, the transmitters are located in Containment and the calibration and maximum Containment temperatures are 50°F and 130°F respectively (Design Input 5.7). Therefore, a maximum change in temperature of 80°F is used to calculate the transmitter temperature effect. Therefore, TExmtr = +/-( 0.15%
+ 0.60% )(
100) TExmtr = +/-(0.15%( 250 108 ) + 0.60% )( 80 100)= +/- 0.76% Span Per Design Input 5.22, the maximum containment temperature when using normal containment setpoint values is 190°F. As discussed above, the minimum containment temperature is 50°F. Therefore, a maximum change in temperature of 140°F is used to calculate the transmitter temperature effect. Therefore, eopTExmtr = +/-( 0.15%
+ 0.60% )(
100) eopTExmtr = +/-(0.15%( 250 108 ) + 0.60% )( 140 100)= = +/-1.33% Span Note: The transmitter temperature effect computed above is for normal environmental conditions only. For accident environmental conditions, the accident temperature effect is included in the loop uncertainty computation.
RNP-I/INST-1070 Revision 14 Page 49 of 105 6.6.6 Normal Transmitter Static Pressure Effect (norSPExmtr) Per Reference 4.4.3, a static pressure span correction is not required on the transmitter. Per Reference 4.4.3, the static pressure span effect correction uncertainty is +/- (0.1% + 0.1% ) per 1000 psi. Per Reference 4.7.9, the maximum normal operating pressure of the Steam Generator is 1020 psia (0% Load). Per Section 9.1, the maximum reading for the transmitter is approximately 138 inwc and the span of each transmitter is 108 inwc. Per Reference 4.4.3, the static pressure zero effect is +/- 0.10% Upper Range Limit per 1000 psi, and the Upper Range Limit of a range code 2 transmitter is 250 inwc. Therefore, the normal static pressure effect for each transmitter is calculated with the following equation: norSPExmtr = +/- 0.1% 250 108 + 0.1% + 0.1%( 250 108 ) 1020 1000 norSPExmtr = +/- 0.57% Span
RNP-I/INST-1070 Revision 14 Page 50 of 105 6.6.7 Accident Transmitter Static Pressure Effect (accSPExmtr) Per Section 9.1, a static pressure span correction is performed on the transmitter. Per Reference 4.4.3, the static pressure span effect correction uncertainty is +/- (0.1% + 0.1% ) per 1000 psi. Per Design Input 5.10, the lowest set pressure of the Steam Generator safety relief valves (1100 psia) is taken as the maximum pressure of the Steam Generator. Per Section 9.1, the maximum reading for the transmitter is approximately 138 inwc and the span of each transmitter is 108 inwc. Per Reference 4.4.3, the static pressure zero effect is +/- 0.10% Upper Range Limit per 1000 psi, and the Upper Range Limit of a range code 2 transmitter is 250 inwc. Therefore, the accident static pressure effect for each transmitter is calculated with the following equation: accSPExmtr = +/- 0.1% 250 108 + 0.1% + 0.1%( 250 108 ) 1100 1000 accSPExmtr = +/- 0.62% Span Note that due to the pressure range of interest in the EOPs, the accSPExmtr value is also applicable during normal containment conditions when in the EOPs. Thus, eopSPExmtr = accSPExmtr = +/- 0.62% Span 6.6.8 Transmitter Power Supply Effect (PSExmtr) Per Reference 4.4.3, the power supply effect associated with the transmitters is given as +/- 0.005% Span per volt variation in power supplied to the transmitter from the power supplied at the time of calibration. Per EDB (Reference 4.7.4), each instrument loop is powered by an NUS SPS 800 power supply. The power supply is powered by regulated instrument buses per Reference 4.2.1. Therefore, the power supply effect is negligible. PSExmtr = N/A
RNP-I/INST-1070 Revision 14 Page 51 of 105 6.6.9 Normal Transmitter Total Device Uncertainty (norTDUxmtr) Per Reference 4.6.6, the Total Device Uncertainty for normal environmental conditions is computed using the following equation: norTDUxmtr = +/- 2 xmtr 2 xmtr 2 xmtr 2 xmtr 2 xmtr 2 xmtr norSPE norTE DR RA ) MTE (CAL + + + + +
+ DRxmtrBIAS Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, norTDUxmtr = +/-
2 xmtr 2 xmtr 2 xmtr 2 xmtr norSPE norTE AD CAL + + +
+ ADxmtrBIAS norTDUxmtr = +/-0.502 + 1.0442 + 0.762 + 0.572 0.227 norTDUxmtr = +/- 1.50% Span, 0.23% Span 6.6.10 Normal Transmitter Total Device Uncertainty (eopTDUxmtr) for EOPs Per Reference 4.6.6, the Total Device Uncertainty for normal environmental conditions for EOPs is computed using the following equation:
eopTDUxmtr = +/- 2 xmtr 2 xmtr 2 xmtr 2 xmtr 2 xmtr 2 xmtr eopSPE eopTE DR RA ) MTE (CAL + + + + +
+ DRxmtrBIAS Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, eopTDUxmtr = +/-
2 xmtr 2 xmtr 2 xmtr 2 eopSPE eopTE AD CAL + + +
+ ADxmtrBIAS eopTDUxmtr = +/-0.502 + 1.0442 + 1.332 + 0.622 0.227 eopTDUxmtr = +/- 1.87% Span, 0.23% Span 6.6.11 Accident Transmitter Total Device Uncertainty (accTDUxmtr)
Per Reference 4.6.6, the Total Device Uncertainty for accident conditions is computed using the following equation:
RNP-I/INST-1070 Revision 14 Page 52 of 105 accTDUxmtr = +/- 2 xmtr 2 xmtr 2 xmtr 2 xmtr 2 xmtr accSPE DR RA ) MTE (CAL + + + +
+ DRxmtrBIAS Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, accTDUxmtr = +/-
2 xmtr 2 xmtr 2 accSPE AD CAL + + + ADxmtrBIAS accTDUxmtr = +/-0.502 + 1.0442 + 0.622 0.23 accTDUxmtr = +/- 1.31% Span, 0.23% Span 6.6.12 Transmitter As Found Tolerance (AFTxmtr) Per Reference 4.6.6, the As Found Tolerance (AFT) is computed using the following equation: AFTxmtr = +/- 2 xmtr 2 xmtr 2 xmtr MTE DR CAL + + AFTxmtr = +/-0.502 + 0.232 + 0.502 AFTxmtr = +/- 0.74% Span Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the AFT, therefore, AFTxmtr = +/- 2 xmtr 2 xmtr AD CAL + AFTxmtr = +/- 2 2 044 .1 50 .0 + AFTxmtr = +/- 1.16% Span Note: The bias portion of the analyzed drift will be captured in the Total Device Uncertainty, the Total Loop Uncertainty, and ultimately included, if appropriate, in the setpoint margin. For conservatism, it will not be included in the AFT. The current AFTxmtr value of +/- 0.74% Span is less than, i.e., more conservative than, the above calculated AFTxmtr value of +/- 1.16% Span. For conservatism, AFTxmtr = +/- 0.74% Span will be retained.
RNP-I/INST-1070 Revision 14 Page 53 of 105 6.6.13 Transmitter As Left Tolerance (ALTxmtr) Per Reference 4.6.6, the As Left Tolerance (ALT) is computed using the following equation: ALTxmtr = CALxmtr ALTxmtr = +/- 0.50% Span Error Contributor Value Type Section RA +/- 0.12% Span Random 6.6.1 CAL +/- 0.50% Span Random 6.6.2 DR +/- 0.23% Span Random 6.6.3 AD +/- 1.044% Span Random 6.6.3 0.227% Span Bias MTE +/- 0.50% Span Random 6.6.4 ATE +/- 3.32% Span Random 6.1.1 ARE +/-1.69% Span Random 6.1.3 SE +/- 1.16% Span Random 6.2 eopTE +/- 1.33% Span Random 6.6.5 norTE +/- 0.76% Span Random 6.6.5 norSPE +/- 0.57% Span Random 6.6.6 accSPE +/- 0.62% Span Random 6.6.7 As Left Tolerance (ALT) +/- 0.50% Span Random 6.6.13 As Found Tolerance (AFT) +/- 0.74% Span Random 6.6.12 Total Device Uncertainty (EOP) +/- 1.87% Span Random 6.6.10 0.23% Span Bias Total Device Uncertainty (non-accident) +/- 1.50 %Span Random 6.6.9 0.23% Span Bias Total Device Uncertainty (accident) +/- 1.31% Span Random 6.6.11 0.23% Span Bias Transmitter Uncertainty Summary
RNP-I/INST-1070 Revision 14 Page 54 of 105 6.7 COMPARATOR MODULE 6.7.1 Comparators Unverified Attributes of Reference Accuracy (RAcomp) Per Reference 4.4.1, the comparator reference accuracy is +/- 0.50% Span. Per References 4.5.2 through 4.5.11, the comparator is calibrated to +/- 0.50% Span, and the calibration procedure verifies the attributes of linearity and hysteresis but not repeatability. Per Reference 4.6.6, the following equation is utilized to compute the repeatability portion of the comparator reference accuracy: Repeatability = +/- 3 RA comp = +/- 3 Span 50 .0 = +/- 0.29% Span Therefore, RAcomp = +/- 0.29% Span 6.7.2 Comparator Calibration Tolerance (CALcomp) Per Reference 4.5.11, the comparator is calibrated to +/- 0.50% Span. Therefore, CALcomp = +/- 0.50% Span 6.7.3 Comparator Drift (DRcomp) Per Reference 4.4.1, no drift is specified for the Hagan or NUS comparator. Per Reference 4.6.6, if no drift is specified for a device, a default value of +/- 1.00% Span may be used. Based on historical data, Hagan comparator drift is +/- 0.25% Span (Attachment B). If the default value bounds the value obtained through a review of the historical data, the default value of +/- 1.00% Span may be used for comparator drift (Reference 4.6.6). Therefore, the default value of +/- 1.00% Span is used for comparator drift for the NUS and Hagan comparators. DRcomp = +/- 1.00% Span The comparator is subject to a quarterly COT per MST-013 (Reference 4.5.13). Therefore, per Design Input 5.26, the above drift value is conservative and will be used. _t _f
RNP-I/INST-1070 Revision 14 Page 55 of 105 6.7.4 Comparator M&TE Effect (MTEcomp) Per References 4.5.2-10, one DMM with an accuracy of +/- 0.25% Reading is used to calibrate the comparator. For conservatism, a maximum reading of 5 Vdc is used to compute the accuracy of the DMM as follows: MTEcomp = ( )
+/- Vdc 4 Vdc 5 Reading 25 .0 = +/- 0.31% Span 6.7.5 Comparator Temperature Effect (TEcomp) Per Reference 4.4.1, the NUS comparator temperature effect is given as +/- 0.04% Span per 1°C change in temperature from the temperature at the time of calibration, and no temperature effect is specified for the Hagan comparator. Per EGR-NGGC-0153 (Reference 4.6.1), if no temperature effect is specified for a device, a default value of +/- 0.50% Span may be used for the temperature effect. Per Design Input 5.8, a change in temperature of 42°F (23.33°C) is used to compute the comparator temperature effect. Therefore, TEcomp = +/- 0.04% Span
° ° C 1 C 33 23 TEcomp = +/- 0.93% Span Since either Westinghouse Hagan or NUS comparator may be used, the most restrictive temperature effect (NUS comparator) is used in this calculation. 6.7.6 Comparator Power Supply Effect (PSEcomp) Per Reference 4.4.1, no uncertainty for the comparator power supply effect is specified. Since the comparators are powered by regulated instrument buses, the comparator power supply effect is considered to be negligible. Therefore, PSEcomp = N/A 6.7.7 Comparator Total Device Uncertainty (TDUcomp) Total Device Uncertainty is computed using the following equation: TDUcomp = +/- ( ) 2 comp 2 comp 2 comp 2 comp comp TE DR RA MTE CAL + + + + TDUcomp = +/- 1.61% Span
RNP-I/INST-1070 Revision 14 Page 56 of 105 6.7.8 Comparator As Found Tolerance (AFTcomp) Per Reference 4.6.6, the As Found Tolerance (AFT) is computed using the following equation: AFTcomp = +/- 2 comp 2 comp 2 comp MTE DR CAL + + AFTcomp = +/- 1.16% Span 6.7.9 Comparator As Left Tolerance (ALTcomp) Per Reference 4.6.6, the As Left Tolerance (ALT) is computed using the following equation: ALTcomp = CALcomp ALTcomp = +/- 0.50% Span Error Contributor Value Type Section RA +/- 0.29% Span Random 6.7.1 CAL +/- 0.50% Span Random 6.7.2 DR +/- 1.00% Span Random 6.7.3 MTE +/- 0.31% Span Random 6.7.4 TE +/- 0.93% Span Random 6.7.5 As Left Tolerance (ALT) +/- 0.50% Span Random 6.7.9 As Found Tolerance (AFT) +/- 1.16% Span Random 6.7.8 Total Device Uncertainty (non-accident) +/- 1.61% Span Random 6.7.7 Comparator Module Uncertainty Summary
RNP-I/INST-1070 Revision 14 Page 57 of 105 6.8 ISOLATOR MODULE 6.8.1 Isolators Unverified Attributes of Reference Accuracy (RAisol) Per Hagan vendor manual 728-589-13 (Reference 4.4.1), the reference accuracy of the NUS 800 isolator is +/-0.1% of output full scale, repeatable to +/- 0.05%, with a linearity better than +/-0.05% of output full scale. Per Hagan vendor manual 728-589-13 (Reference 4.4.1), the reference accuracy of the NUS EIP isolator is +/-0.1% of full scale, with a linearity better than +/-0.1% of full scale output. Per LP-027 through LP-035 and MMM-06 (References 4.5.2 through 4.5.11), the isolator is calibrated to +/- 0.50% Span, and the calibration procedure verifies the attributes of linearity but not hysteresis or repeatability. Per Reference 4.6.6, the following equation is used to compute the repeatability portion of the NUS EIP isolator reference accuracy: Repeatability = +/- 3 RAisol = +/- 3 Span 10 .0 = +/- 0.06% Span For conservatism, Repeatability = +/- 0.06% P Span will be assigned to both the NUS 800 and NUS EIP isolators. Per Reference 4.6.6, the following equation is used to compute the hysteresis portion of both the NUS 800 and NUS EIP isolator reference accuracy: Hysteresis = +/- 3 RAisol = +/- 3 Span 10 .0 = +/- 0.06% Span The NUS 800 and NUS EIP isolator reference accuracy is now determined by combining the attributes of the hysteresis and repeatability calculated above, using the SRSS method. RAisol = +/- 2 2 0.06 0.06 + RAisol = +/-0.08% Span 6.8.2 Isolator Calibration Tolerance (CALisol) Per Reference 4.5.11, the isolator is calibrated to +/- 0.50% Span. Therefore, CALisol = +/- 0.50% Span 6.8.3 Isolator Drift (DRisol) Per Reference 4.4.1, no uncertainty for isolator drift is specified. The default value of +/- 1.00% Span is used to represent isolator drift [Reference 4.6.6]. Therefore, DRisol = +/- 1.00% Span
RNP-I/INST-1070 Revision 14 Page 58 of 105 NUS 800 Isolator Drift (DR800isol) Per Attachments F (Reference 4.7.23) and G (Reference 4.7.24), the NUS 800 isolator drift has been tested to be less than +/-0.20% Span for calibration intervals of up to 36 months, which bounds the 30 month requirement for these isolators. For conservatism, DR800isol = +/- 1.00% Span will be retained. NUS EIP Isolator Drift (DREIPisol) Per Hagan vendor manual 728-589-13 (Reference 4.4.1), no drift uncertainty for the NUS EIP isolator is specified. Per Reference 4.6.6, the default value of +/- 1.00% Span/18 months is used to represent the isolator drift. Per Design Input 5.28, as part of the 24 month fuel cycle project, the nominal calibration interval is being extended to 24 months with a maximum of 30 months (24 months + 25%). Per EGR-NGGC-0153 (Reference 4.6.1), when the calibration interval exceeds the vendor specified drift interval (default value in this instance), treatment of the drift as random and independent with respect to the multiple time intervals is the preferred methodology. Accordingly, the SRSS method will be used to combine the +/- 1.0% Span/18 month drift intervals. The number of drift intervals = 30 months/18 months = 1.67. Calculating DREIPisol, DREIPisol = +/- ) 0.1( 67 .1 2 DREIPisol = +/- 1.29% Span 6.8.4 Isolator M&TE Effect (MTEisol) Per References 4.5.2-10, two DMMs are used to calibrate the isolator. Each DMM has an accuracy of +/- 0.25% Reading. The total MTE term is the SRSS of the individual DMM accuracy terms. For conservatism, a maximum reading of 5 Vdc is used to compute the accuracy of the DMMs as follows: MTEisol = ( ) ( )
+/- 2 Vdc 4 Vdc 5 Reading 25 .0 2 MTEisol = +/- 0.44% Span 6.8.5 Isolator Temperature Effect (TEisol) .J
RNP-I/INST-1070 Revision 14 Page 59 of 105 Per Hagan vendor manual 728-589-13 (Reference 4.4.1), the NUS EIP isolator temperature effect is +/- 0.01% full scale/°C. Per Reference 4.4.1, the NUS 800 isolator temperature effect is less than +/- 0.50% of output full scale per 50°F for module gains less than 1.7. Per Design Input 5.8, a change in temperature of 42°F (23.33°C) is used to compute the isolator temperature effect for normal conditions, and a change in temperature of 70°F. NUS EIP Isolator Temperature Effect for Normal Conditions (norTEEIPisol) For a temperature change of 42°F (23.33°C), norTEEIPisol is computed as follows: norTEEIPisol = +/- 0.01% Full Scale
° °
C 1 C 23.33 Vdc 4 Span 100 Scale Full 100% Vdc 5 norTEEIPisol = +/- 0.29% Span NUS 800 Isolator Temperature Effect for Normal Conditions (norTE800isol) For a temperature change of 42°F, norTE800isol is computed as follows: norTE800isol = +/- 0.50% Full Scale
° °
F 50 F 42 Vdc 4 Span 100 Scale Full 100% Vdc 5 norTE800isol = +/- 0.53% Span NUS EIP Isolator Temperature Effect for Accident Conditions (accTEEIPisol) For a temperature change of 70°F (38.89°C), accTEEIPisol is computed as follows: accTEEIPisol = +/-0.01% Full Scale
° °
C 1 C 38.89 Vdc 4 Span 100% Scale Full 100% Vdc 5 accTEEIPisol = +/-0.49% Span NUS 800 Isolator Temperature Effect for Accident Conditions (accTE800isol) For a temperature change of 70°F, accTE800isol is computed as follows: accTE800isol = +/-0.50% Full Scale
° °
F 50 F 70 Vdc 4 Span 100 Scale Full 100% Vdc 5 accTE800isol = +/-0.88% Span 6.8.6 Isolator Power Supply Effect (PSEisol)
RNP-I/INST-1070 Revision 14 Page 60 of 105 Per Reference 4.4.1, no uncertainty for the isolator power supply effect is specified. Since the isolators are powered by regulated instrument buses, the isolator power supply effect is considered to be negligible. Therefore, PSEisol = N/A 6.8.7 Isolator Total Device Uncertainty (TDUisol) NUS EIP Isolator TDU for Normal conditions (norTDUEIPisol) Per Reference 4.6.6, the Total Device Uncertainty is computed using the following equation: norTDUEIPisol = +/- ( ) 2 EIPisol 2 EIPisol 2 isol 2 isol isol norTE DR RA MTE CAL + + + + norTDUEIPisol = +/- ( ) 2 2 2 2 29 .0 29 .1 08 .0 44 .0 50 .0 + + + + norTDUEIPisol = +/- 1.62% Span NUS 800 Isolator TDU for Normal Conditions (norTDU800isol) Per Reference 4.6.6, the Total Device Uncertainty is computed using the following equation: norTDU800isol = +/- ( ) 2 isol 800 2 isol 800 2 isol 2 isol isol norTE DR RA MTE CAL + + + + norTDU800isol = +/- ( ) 2 2 2 2 53 .0 00 .1 08 .0 44 .0 50 .0 + + + + norTDU800isol = +/- 1.47% Span NUS EIP Isolator TDU for Accident Conditions (accTDUEIPisol) Per Reference 4.6.6, the Total Device Uncertainty is computed using the following equation: accTDUEIPisol = +/- ( ) 2 EIPisol 2 EIPisol 2 isol 2 isol isol accTE DR RA MTE CAL + + + + accTDUEIPisol = +/- ( ) 2 2 2 2 49 .0 29 .1 08 .0 44 .0 50 .0 + + + + accTDUEIPisol = +/- 1.67% Span NUS 800 Isolator TDU for Accident Conditions (accTDU800isol) Per Reference 4.6.6, the Total Device Uncertainty is computed using the following equation:
RNP-I/INST-1070 Revision 14 Page 61 of 105 accTDU800isol = +/- ( ) 2 isol 800 2 isol 800 2 isol 2 isol isol accTE DR RA MTE CAL + + + + accTDU800isol = +/- ( ) 2 2 2 2 88 .0 00 .1 08 .0 44 .0 50 .0 + + + + accTDU800isol = +/- 1.63% Span For conservatism, norTDUEIPisol, norTDU800isol, and accTDU800isol will be assigned the accTDUEIPisol uncertainty value of +/- 1.67% Span for both accident and non-accident (normal) conditions. 6.8.8 Isolator As Found Tolerance (AFTisol) NUS 800 Isolator As Found Tolerance (AFT800isol) Per EGR-NGGC-0153, the As Found Tolerance (AFT) is computed using the following equation: AFT800isol = +/- 2 isol 2 isol 800 2 isol MTE DR CAL + + AFT800isol = +/- 2 2 2 44 .0 00 .1 50 .0 + + AFT800isol = +/- 1.20% Span NUS EIP Isolator As Found Tolerance (AFT800isol) Per Reference 4.6.6, the As Found Tolerance is computed using the following equation: AFTEIPisol = +/- 2 isol 2 EIPisol 2 isol MTE DR CAL + + AFTEIPisol = +/- 2 2 2 44 .0 29 .1 50 .0 + + AFTEIPisol = +/- 1.45% Span The current AFTEIPisol value of +/- 1.20% Span is less than, i.e., more conservative than, the above calculated AFTEIPisol value of +/- 1.45% Span. For conservatism, AFTEIPisol = +/- 1.20% Span will be retained. 6.8.9 Isolator As Left Tolerance (ALTisol) Per Reference 4.6.6, the As Left Tolerance (ALT) is computed using the following equation: ALT800isol = CALisol = +/- 0.50% Span
RNP-I/INST-1070 Revision 14 Page 62 of 105 ALTEIPisol = CALisol = +/- 0.50% Span Error Contributor Value Type Section RA +/- 0.08% Span Random 6.8.1 CAL +/- 0.50% Span Random 6.8.2 DR +/- 1.00% Span Random 6.8.3 DR800isol +/- 1.00% Span Random 6.8.3 DREIPisol +/- 1.29% Span Random 6.8.3 MTE +/- 0.44% Span Random 6.8.4 norTE800isol +/- 0.53% Span Random 6.8.5 norTEEIPisol +/- 0.29% Span Random 6.8.5 accTE800isol +/- 0.88% Span Random 6.8.5 accTEEIPisol +/-0.49% Span Random 6.8.5 As Left Tolerance (ALT) +/- 0.50% Span Random 6.8.9 As Found Tolerance (AFT) +/- 1.20% Span Random 6.8.8 Total Device Uncertainty (accident) +/- 1.67% Span Random 6.8.7 Total Device Uncertainty (non-accident) +/-1.67% Span Random 6.8.7 Isolator Module Uncertainty Summary Note: RA, CAL, MTE, ALT, and AFT values are equalvalent for both isolators.
RNP-I/INST-1070 Revision 14 Page 63 of 105 6.9 INDICATOR 6.9.1 Indicators Unverified Attributes of Reference Accuracy (RAind) Per Reference 4.4.2, the reference accuracy of the indicator is +/- 2.00% Span and includes the effects of linearity, hysteresis, and repeatability (Design Input 5.5). Per References 4.5.2 through 4.5.11, the indicator is calibrated to +/- 2.00% Span at nine points (5 up and 4 down). Therefore, the calibration procedure verifies the attributes of linearity and hysteresis but not repeatability. Per Reference 4.6.6, the following equation is utilized to compute the repeatability portion of the indicator reference accuracy: Repeatability = +/- 3 RAind = +/- 3 Span 00 .2 = +/- 1.15% Span Therefore, RAind = +/- 1.15% Span 6.9.2 Indicator Calibration Tolerance (CALind) Per Reference 4.5.11, the indicator is calibrated to +/- 2.00% Span. Therefore, CALind = +/- 2.00% Span 6.9.3 Indicator Drift (DRind) Per Attachment D, indicator drift is specified as +/- 1.00% Span per year. Per Reference 4.6.6, the time interval between calibrations is 22.5 month (18 months + 25%), and the following equation is used to compute the indicator drift: DRind = +/-
months 12 months 22.5 Span 00 .1 DRind = +/- 1.37% Span Based on historical As-Found/As-Left data from calibration records, RNP-I/INST-1215 (Reference 4.2.8) determined a bounding 30 month analyzed drift (AD) value of +/-1.792% Span, which is to be treated as a random 2 value term with no significant bias term. Since the current drift value of +/-1.37% Span does not bound the AD value for the current calibration interval or the extended 30 month interval, the AD value will be used in this calculation, therefore, ADind = +/- 1.792% Span
RNP-I/INST-1070 Revision 14 Page 64 of 105 6.9.4 Indicator M&TE Effect (MTEind) Per Reference 4.5.2-10, one DMM with an accuracy of +/- 0.25% Reading is used to calibrate the indicator. The calibration points are cardinal points on the indicator scale (Reference 4.5.2-10). Therefore, the indicator resolution is not included in the MTE term. For conservatism, a maximum reading of 5 Vdc is used to compute the accuracy of the DMM as follows: MTEind = ( )
+/- Vdc 4 Vdc 5 Reading 25 .0 = +/- 0.31% Span 6.9.5 Indicator Temperature Effect (TEind) Per Attachment D, the indicator temperature effect is specified as +/-0.10% Span per 1°C change from the temperature at the time of calibration. Per Design Input 5.14, a change in temperature of 11.1°C is used to compute the indicator temperature effect. TEind = +/-
° ° C 1 C 11.1 Span 0.10% TEind = +/- 1.11% Span 6.9.6 Indicator Power Supply Effect (PSEind) Per References 4.1.1 through 4.1.8, the indicators are not powered by an external source. Therefore, there is no indicator power supply effect. PSEind = N/A 6.9.7 Indicator Readability (RDind) Per Reference 4.6.6, the indicator readability term is 1/2 of the smallest indicator scale demarcation. Per References 4.1.11 and 4.1.12, the indicator has a scale of 0 to 100% with minor demarcations of 2%. Therefore, RDind = +/-
100% Span 100 2 2% = +/- 1.00% Span
RNP-I/INST-1070 Revision 14 Page 65 of 105 6.9.8 Indicator Total Device Uncertainty (TDUind) Per Reference 4.6.6, the Total Device Uncertainty is computed using the following equation: TDUind = +/- ( ) 2 ind 2 ind 2 ind 2 ind 2 ind ind RD TE DR RA MTE CAL + + + + + TDUind = +/- ( ) 2 2 2 2 2 00 .1 11 .1 37 .1 15 .1 31 .0 00 .2 + + + + + TDUind = +/- 3.28% Span Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, TDUind = +/- 2 ind 2 ind 2 ind 2 ind RD TE AD CAL + + + TDUind = +/- 2 2 2 2 00 .1 11 .1 792 .1 00 .2 + + + TDUind = +/- 3.07% Span 6.9.9 Indicator Total Device Uncertainty for EOP Setpoints (eopTDUind) Per Input 5.20, indicator readability is not required for EOP setpoint applications. Per Reference 4.6.6, the Total Device Uncertainty for EOP setpoints is computed using the following equation: eopTDUind = +/- ( ) 2 ind 2 ind 2 ind 2 ind ind TE DR RA MTE CAL + + + + eopTDUind = +/- ( ) 2 2 2 2 11 .1 37 .1 15 .1 31 .0 00 .2 + + + + eopTDUind = +/- 3.13% Span Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, eopTDUind = +/- 2 ind 2 ind 2 ind TE AD CAL + + eopTDUind = +/- 2 2 2 11 .1 792 .1 00 .2 + + eopTDUind = +/- 2.91% Span
RNP-I/INST-1070 Revision 14 Page 66 of 105 6.9.10 Indicator As Found Tolerance (AFTind) Per Reference 4.6.6, the As Found Tolerance (AFT) is computed using the following equation: AFTind = +/- 2 ind 2 ind 2 ind MTE DR CAL + + AFTind = +/- 2 2 2 31 .0 37 .1 00 .2 + + AFTind = +/- 2.44% Span Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the AFT, therefore, AFTind = +/- 2 ind 2 ind AD CAL + AFTind = +/- 2 2 792 .1 00 .2 + AFTind = +/- 2.69% Span The current AFTind value of +/- 2.44% Span is less than, i.e., more conservative than, the above calculated AFTind value of +/- 2.69% Span. Therefore, for conservatism, AFTind = +/- 2.44% Span will be retained.
RNP-I/INST-1070 Revision 14 Page 67 of 105 6.9.11 Indicator As Left Tolerance (ALTind) Per Reference 4.6.6, the As Left Tolerance (ALT) is computed using the following equation: ALTind = CALind ALTind = +/- 2.00% Span Error Contributor Value Type Section RA +/- 1.15% Span Random 6.9.1 CAL +/- 2.00% Span Random 6.9.2 DR +/- 1.37% Span Random 6.9.3 AD +/- 1.792% Span Random 6.9.3 MTE +/- 0.31% Span Random 6.9.4 TE +/- 1.11% Span Random 6.9.5 RD +/- 1.00% Span Random 6.9.7 As Left Tolerance (ALT) +/- 2.00% Span Random 6.9.11 As Found Tolerance (AFT) +/- 2.44% Span Random 6.9.10 Total Device Uncertainty (EOP) +/- 2.91% Span Random 6.9.9 Total Device Uncertainty (non-accident) +/- 3.07% Span Random 6.9.8 Indicator Uncertainty Summary
RNP-I/INST-1070 Revision 14 Page 68 of 105 6.10 RECORDER 6.10.1 Recorders Unverified Attributes of Reference Accuracy (RArec) Per References 4.1.7, 4.1.8 and 4.1.16, the recorder input span is 1 to 5 Vdc. Therefore, the specifications for a 6 Vdc input range are used to compute the recorder Reference Accuracy. Per Reference 4.4.5, for a 6 Vdc input range, the maximum resolution of the input is 1 mVdc (0.001 Vdc) and the Measurement Accuracy for the recorder is given as +/- (0.05% of reading + 3 digits). Therefore, the recorder Reference Accuracy (RArec) is calculated as follows: RArec = +/- (0.05% Reading + 3 digits) RArec = +/- (0.05% x 5 Vdc + 3 digits) RArec = +/- (0.0025 Vdc + 0.003 Vdc) = +/- 0.0055 Vdc RArec = +/- ( 0.0055 4 )100% Span RArec = +/- 0.14% Span 6.10.2 Recorder Calibration Tolerance (CALrec) Per Reference 4.5.11, the recorder is calibrated to +/- 0.50% Span. Therefore, CALrec = +/- 0.50% Span
RNP-I/INST-1070 Revision 14 Page 69 of 105 6.10.3 Recorder Drift (DRrec) Per Section 5.19, no recorder drift is specified and recorder drift is assumed to be included in the Reference Accuracy and Temperature Effect specifications. Therefore, DRrec = N/A 6.10.4 Recorder M&TE Effect (MTErec) Per References 4.5.2 through 4.5.4, one DMM with an accuracy of +/- 0.25% Reading is used to calibrate the recorder. For conservatism, a maximum reading of 5 Vdc is used to compute the accuracy of the DMM as follows: MTErec = = +/- 0.31% Span 6.10.5 Recorder Temperature Effect (TErec) Per Reference 4.4.5, the Recorder Ambient Temperature Effect is given as +/- (0.1% of reading + 0.05% range) for ambient temperature variation of 10°C (18°F). Per EDB, the recorder is located in the Control Room. Per References 4.1.7, 4.1.8 and 4.1.16, the input range of the recorder is 1 to 5 Vdc. Per Section 5.14, a maximum Control Room temperature variation of 20°F is bounding for this application. Therefore, the Recorder Temperature Effect (TErec) is calculated as follows: TErec = +/- (0.1% Reading + 0.05% range) (20°F/18°F) TErec = +/- (0.1% x 5 Vdc + 0.05% range) (20°F/18°F) TErec = +/- (0.005 Vdc + 0.003 Vdc) (20°F/18°F) = +/- 0.0089 Vdc TErec = +/- ( 0.0089 4 )100% Span TErec = +/- 0.22% Span 6.10.6 Recorder Power Supply Effect (PSErec) Per Reference 4.4.5, the power supply effect for a variation within 90 to 132 Vac is within measurement accuracy. Per Reference 4.2.1, power variation will remain within this band. Therefore, ( )
+/- Vdc 4 Vdc 5 Reading 0.25%
RNP-I/INST-1070 Revision 14 Page 70 of 105 PSErec = N/A 6.10.7 Recorder Readability (RDrec) Per Reference 4.4.5, for a 6 Vdc Volt Range recorder minimum recorder resolution is 0.001 Vdc. The recorders have an input span of 4 Vdc (1 to 5 Vdc). Therefore, RDrec = +/-
Vdc 0.4 Vdc 0.001 100% Span = +/- 0.03% Span Per EGR-NGGC-0153 (Reference 4.6.1), uncertainties less than or equal to 0.05% Span have a negligible effect on the calculation results and may be omitted from the calculation. Therefore, RDrec = N/A 6.10.8 Recorder Total Device Uncertainty (TDUrec) Total Device Uncertainty is computed using the following equation: TDUrec = +/- ( ) 2 rec 2 rec 2 rec rec TE RA MTE CAL + + + TDUrec = +/-(0.50 + 0.31)2 + 0.142 + 0.222 TDUrec = +/- 0.85% Span 6.10.9 Recorder As-Found Tolerance (AFTrec) Per Reference 4.6.6, the As Found Tolerance (AFT) is computed using the following equation: AFTrec = +/- 2 rec 2 rec MTE CAL + AFTrec = +/- 0.59% Span
RNP-I/INST-1070 Revision 14 Page 71 of 105 6.10.10 Recorder As Left Tolerance (ALTrec) Per Reference 4.6.6, the As Left Tolerance (ALT) is computed using the following equation: ALTrec = CALrec ALTrec = +/- 0.50% Span Error Contributor Value Type Section RA +/- 0.14% Span Random 6.10.1 CAL +/- 0.50% Span Random 6.10.2 DR N/A Random 6.10.3 MTE +/- 0.31% Span Random 6.10.4 TE +/- 0.22% Span Random 6.10.5 RD N/A Random 6.10.7 As Left Tolerance (ALT) +/- 0.50% Span Random 6.10.10 As Found Tolerance (AFT) +/- 0.59% Span Random 6.10.9 Total Device Uncertainty (non-accident) +/- 0.85% Span Random 6.10.8 Recorder Uncertainty Summary
RNP-I/INST-1070 Revision 14 Page 72 of 105 7.0 TOTAL LOOP UNCERTAINTY (TLU) 7.1 TOTAL LOOP UNCERTAINTY - PLANT NORMAL 7.1.1 Total Loop Uncertainty - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, AND 496 Per Reference 4.6.6, the total loop uncertainty associated with the indicator is computed with the following equation: TLUind = +/- 2 ind 2 isol 2 xmtr TDU TDU norTDU + + + norPME + ADxmtrBIAS TLUind = +/-1.502 + 1.672 + 3.072 + norPME 0.23 TLUind = +/- 3.80% Span + norPME% Span 0.23% Span Fluid Height (% Span) Fluid Height (in.) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) Positive norPME (% Span) Negative norPME (% Span) 0.00 0.00 +/-3.80 0.23 1.83 8.38 16.00 22.96 +/-3.80 0.23 1.06 8.37 30.00 43.05 +/-3.80 0.23 NA 9.81 50.00 71.75 +/-3.80 0.23 NA 10.55 75.00 107.63 +/-3.80 0.23 NA 12.39 100.00 143.50 +/-3.80 0.23 NA 14.01 Combined Uncertainties Fluid Height (% Span) Fluid Height (in.) Positive TLU (% Span) Negative TLU (% Span) 0.00 0.00 5.63 12.41 16.00 22.96 4.86 12.40 30.00 43.05 3.80 13.84 50.00 71.75 3.80 14.58 75.00 107.63 3.80 16.42 100.00 143.50 3.80 18.04
RNP-I/INST-1070 Revision 14 Page 73 of 105 7.1.2 Total Loop Uncertainty - Input to ERFIS Per Reference 4.6.6, the total loop uncertainty at the input to ERFIS is computed with the following equation: TLUERFIS = +/- 2 isol 2 isol 2 xmtr TDU TDU norTDU + + + norPME + ADxmtrBIAS TLUERFIS = +/-1.502 + 1.672 + 1.672+ norPME 0.23 TLUERFIS = +/- 2.80% Span + norPME% Span 0.23% Span Fluid Height (% Span) Fluid Height (in.) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) Positive norPME (% Span) Negative norPME (% Span) 0.00 0.00 +/-2.80 0.23 1.83 8.38 16.00 22.96 +/-2.80 0.23 1.06 8.37 30.00 43.05 +/-2.80 0.23 NA 9.81 50.00 71.75 +/-2.80 0.23 NA 10.55 75.00 107.63 +/-2.80 0.23 NA 12.39 100.00 143.50 +/-2.80 0.23 NA 14.01 Combined Uncertainties Fluid Height (% Span) Fluid Height (in.) Positive TLU (% Span) Negative TLU (% Span) 0.00 0.00 4.63 11.41 16.00 22.96 3.86 11.40 30.00 43.05 2.80 12.84 50.00 71.75 2.80 13.58 75.00 107.63 2.80 15.42 100.00 143.50 2.80 17.04
RNP-I/INST-1070 Revision 14 Page 74 of 105 7.1.3 Total Loop Uncertainty - Recorder FR-478, 488, & 498 Per Reference 4.6.6, the total loop uncertainty associated with the recorder is computed with the following equation: TLUrec = +/- 2 rec 2 isol 2 xmtr TDU TDU norTDU + + + norPME + ADxmtrBIAS TLUrec = +/-1.502 + 1.672 + 0.852+ norPME 0.23 TLUrec = +/- 2.40% Span + norPME% Span 0.23% Span Fluid Height (% Span) Fluid Height (in) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) Positive norPME (% Span) Negative norPME (% Span) 0.00 0.00 +/-2.40 0.23 1.83 8.38 16.00 22.96 +/-2.40 0.23 1.06 8.37 30.00 43.05 +/-2.40 0.23 NA 9.81 50.00 71.75 +/-2.40 0.23 NA 10.55 75.00 107.63 +/-2.40 0.23 NA 12.39 100.00 143.50 +/-2.40 0.23 NA 14.01 Combined Uncertainties Fluid Height (% Span) Fluid Height (in) Positive TLU (% Span) Negative TLU (% Span) 0.00 0.00 4.23 11.01 16.00 22.96 3.46 11.00 30.00 43.05 2.40 12.44 50.00 71.75 2.40 13.18 75.00 107.63 2.40 15.02 100.00 143.50 2.40 16.64
RNP-I/INST-1070 Revision 14 Page 75 of 105 7.1.4 Total Loop Uncertainty - High Level Alarm LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 (switch 2) Per Reference 4.6.6, the total loop uncertainty associated with the comparators which provide the High Steam Generator Level alarm is computed with the following equation: TLUcomp = +/- 2 comp 2 xmtr TDU norTDU + + norPME @ 75% Level + ADxmtrBIAS TLUcomp = +/-1.502 + 1.612 12.39 0.23 TLUcomp = +/- 2.20% Span 12.62% Span TLUcomp = + 2.20% Span, 14.82% Span 7.1.5 Total Loop Uncertainty - Low Low Level Alarm LC-474A, 475A, 476A, 484A, 485A, 486A, 494A, 495A, & 496A (switch 2) Per Reference 4.6.6, the total loop uncertainty associated with the comparators which provide the Low Low Steam Generator Level alarm is computed with the following equation: TLUcomp = +/- 2 comp 2 xmtr TDU norTDU + + norPME @16% Level + ADxmtrBIAS TLUcomp = +/-1.502 + 1.612+ 1.06 8.37 0.23 TLUcomp = +/- 2.20% Span +1.06% Span 8.60% Span TLUcomp = +3.26% Span, 10.80% Span 7.1.6 Total Loop Uncertainty - Low Level Alarm LC-474B, 475B, 484B, 485B, 494B, 495B Per Reference 4.6.6, the total loop uncertainty associated with the comparators which provide the Low Steam Generator Level alarm are computed with the following equation: TLUcomp = +/- 2 comp 2 xmtr TDU norTDU + + norPME @ 30% + ADxmtrBIAS TLUcomp = +/-1.502 + 1.612 9.81 0.23 TLUcomp = +/- 2.20% Span 10.04% Span TLUcomp = +2.20% Span, 12.24% Span 7.1.7 Total Loop Uncertainty - Input to AMSAC
RNP-I/INST-1070 Revision 14 Page 76 of 105 Per Reference 4.6.6, the total loop uncertainty associated with the input to AMSAC are computed with the following equation: TLUAMSAC = +/- 2 isol 2 xmtr TDU norTDU + + norPME + ADxmtrBIAS TLUAMSAC = +/-1.502 + 1.672+ norPME 0.23 TLUAMSAC = +/- 2.24% Span + norPME% Span 0.23% Span Fluid Height (% Span) Fluid Height (in.) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) Positive norPME (% Span) Negative norPME (% Span) 0.00 0.00 +/-2.24 0.23 1.83 8.38 16.00 22.96 +/-2.24 0.23 1.06 8.37 30.00 43.05 +/-2.24 0.23 NA 9.81 50.00 71.75 +/-2.24 0.23 NA 10.55 75.00 107.63 +/-2.24 0.23 NA 12.39 100.00 143.50 +/-2.24 0.23 NA 14.01 Combined Uncertainties Fluid Height (% Span) Fluid Height (in.) Positive TLU (% Span) Negative TLU (% Span) 0.00 0.00 4.07 10.85 16.00 22.96 3.30 10.84 30.00 43.05 2.24 12.28 50.00 71.75 2.24 13.02 75.00 107.63 2.24 14.86 100.00 143.50 2.24 16.48
RNP-I/INST-1070 Revision 14 Page 77 of 105 7.1.8 Total Loop Uncertainty for use in the EOPs - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, AND 496 Per Reference 4.6.6, the total loop uncertainty associated with the indicator, for normal conditions (15 psia to 1100 psia SG pressure) and 88°F to 190°F (Ref Leg temp), is computed with the following equation: TLUind = +/- 2 ind 2 isol 2 xmtr eopTDU TDU eopTDU + + + eopPME + ADxmtrBIAS TLUind = +/-1.872 + 1.672 + 2.912+ eopPME 0.23 TLUind = +/- 3.84% Span + eopPME% Span 0.23% Span Note: The eopPME values were determined in Section 6.4.3. Fluid Height (% Span) Fluid Height (in.) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) Positive eopPME (% Span) Negative eopPME (% Span) 0.00 0.00 +/- 3.84 0.23 3.84 4.71 16.00 22.96 +/- 3.84 0.23 3.41 1.26 30.00 43.05 +/- 3.84 0.23 7.20 2.45 50.00 71.75 +/- 3.84 0.23 12.60 4.16 75.00 107.63 +/- 3.84 0.23 19.36 6.30 100.00 143.50 +/- 3.84 0.23 26.12 8.44 Combined Uncertainties Fluid Height (% Span) Fluid Height (in) Positive TLU (% Span) Negative TLU (% Span) 0.00 0.00 7.68 8.78 16.00 22.96 7.25 5.33 30.00 43.05 11.04 6.52 50.00 71.75 16.44 8.23 75.00 107.63 23.20 10.37 100.00 143.50 29.96 12.51
RNP-I/INST-1070 Revision 14 Page 78 of 105 7.2 TOTAL LOOP UNCERTAINTY - ACCIDENT 7.2.1 Total Loop Uncertainty - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, & 496 Per Reference 4.6.6, the total loop uncertainty associated with the indicator is computed with the following equation: TLUind = +/- 2 xmtr 2 xmtr 2 ind 2 isol 2 xmtr ARE ATE TDU TDU accTDU + + + + + IR + accPME
+ ADxmtrBIAS TLUind = +/-1.312 + 1.672 + 3.072 + 3.322 + 1.692+ IR + accPME 0.23 TLUind = +/- 5.27% Span + IR% Span + accPME% Span 0.23% Span Note: The IR value was determined in Section 6.3 and the accPME values were determined in Section 6.4.2, and include FVE, DSE and FRE. Also note the IR effects are a positive bias and thus, not included in the negative TLU calculation.
Fluid Height (% Span) Fluid Height (in.) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) IR (% Span) Posititve accPME (% Span) Negative accPME (% Span) 0.00 0.00 +/-5.27 0.23 2.21 13.71 11.72 16.00 22.96 +/-5.27 0.23 2.21 12.65 7.94 30.00 43.05 +/-5.27 0.23 2.21 10.24 10.13 50.00 71.05 +/-5.27 0.23 2.21 14.08 11.21 75.00 107.63 +/-5.27 0.23 2.21 20.93 13.26 100.00 143.5 +/-5.27 0.23 2.21 27.78 15.31 Combined Uncertainties Fluid Height (% Span) Fluid Height (in.) Posititve TLU (% Span) Negative TLU (% Span) 0.00 0.00 21.19 17.22 16.00 22.96 20.13 13.44 30.00 43.05 17.72 15.63 50.00 71.05 21.56 16.71 75.00 107.63 28.41 18.76 100.00 143.5 35.26 20.81
RNP-I/INST-1070 Revision 14 Page 79 of 105 7.2.2 Total Loop Uncertainty - Recorder FR-478, 488, & 498 Per Reference 4.6.6, the total loop uncertainty associated with the recorder is computed with the following equation: TLUrec = +/- 2 xmtr 2 xmtr 2 rec 2 isol 2 xmtr ARE ATE TDU TDU accTDU + + + + + IR + accPME
+ ADxmtrBIAS TLUrec = +/-1.312 + 1.672 + 0.852 + 3.322 + 1.692+ IR + accPME 0.23 TLUrec = +/- 4.37% Span + IR% Span + accPME% Span 0.23% Span Note: The IR value was determined in Section 6.3 and the accPME values were determined in Section 6.4.2, and include FVE, DSE and FRE. Also note the IR effects are a positive bias and thus, not included in the negative TLU calculation.
Fluid Height (% Span) Fluid Height (in.) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) IR (% Span) Positive accPME (% Span) Negative accPME (% Span) 0.00 0.00 +/-4.37 0.23 2.21 13.71 11.72 16.00 22.96 +/-4.37 0.23 2.21 12.65 7.94 30.00 43.05 +/-4.37 0.23 2.21 10.24 10.13 50.00 71.75 +/-4.37 0.23 2.21 14.08 11.21 75.00 107.63 +/-4.37 0.23 2.21 20.93 13.26 100.00 143.50 +/-4.37 0.23 2.21 27.78 15.31 Combined Uncertainties Fluid Height (% Span) Fluid Height (in.) Positive TLU (% Span) Negative TLU (% Span) 0.00 0.00 20.29 16.32 16.00 22.96 19.23 12.54 30.00 43.05 16.82 14.73 50.00 71.75 20.66 15.81 75.00 107.63 27.51 17.86 100.00 143.50 34.36 19.91
RNP-I/INST-1070 Revision 14 Page 80 of 105 7.2.3 Total Loop Uncertainty - Input to ERFIS Per Reference 4.6.6, the total loop uncertainty at the input to ERFIS is computed with the following equation: TLUERFIS = +/- 2 xmtr 2 xmtr 2 isol 2 isol 2 xmtr ARE ATE TDU TDU accTDU + + + + + IR + accPME
+ ADxmtrBIAS TLUERFIS = +/-1.312 + 1.672 + 1.672 + 3.322 + 1.692+ IR + accPME 0.23 TLUERFIS = +/- 4.60% Span + IR% Span + accPME% Span 0.23% Span Note: The IR value was determined in Section 6.3 and the accPME values were determined in Section 6.4.2, and include FVE, DSE and FRE. Also note the IR effects are a positive bias and thus, not included in the negative TLU calculation.
Fluid Height (% Span) Fluid Height (in.) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) IR (% Span) Positive accPME (% Span) Negative accPME (% Span) 0.00 0.00 +/- 4.60 0.23 2.21 13.71 11.72 16.00 22.96 +/- 4.60 0.23 2.21 12.65 7.94 30.00 43.05 +/- 4.60 0.23 2.21 10.24 10.13 50.00 71.75 +/- 4.60 0.23 2.21 14.08 11.21 75.00 107.63 +/- 4.60 0.23 2.21 20.93 13.26 100.00 143.50 +/- 4.60 0.23 2.21 27.78 15.31 Combined Uncertainties Fluid Height (% Span) Fluid Height (in.) Positive Uncertainty (% Span) Negative Uncertainty (% Span) 0.00 0.00 20.52 16.55 16.00 22.96 19.46 12.77 30.00 43.05 17.05 14.96 50.00 71.75 20.89 16.04 75.00 107.63 27.74 18.09 100.00 143.50 34.59 20.14
RNP-I/INST-1070 Revision 14 Page 81 of 105 7.2.4 Total Loop Uncertainty - Low Low Level Reactor Trip Although the Low Low Level Reactor Trip occurs at 16% level, the PME values for 0% level are used below. This is conservative and allows for additional margin. LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 (switch 1) Uncertainties for Feedwater Line Break Accident Per Reference 4.6.6, the total loop uncertainty associated with the comparators that provide the Low Low Steam Generator Level Reactor Trip is computed with the following equation: TLUcomp = +/- 2 xmtr 2 comp 2 xmtr ATE TDU accTDU + + + IR + accPME @ 0% Level
+ ADxmtrBIAS TLUcomp = +/-1.312 + 1.612 + 3.322+ 2.21 + 5.79 11.72 0.23 TLUcomp = +/- 3.92% Span + 8.00% Span 11.95% Span TLUcomp = +11.92% Span, 15.87% Span The accPME in this case is taken from the specific case for a Feedwater Line Break Accident. This is acceptable as the conditions that result from a Main Steam Line Break (MSLB) are overly conservative and the Low Low Steam Generator Trip is not credited in an MSLB accident.
Uncertainties for Loss of Offsite Power and for Loss of Normal Feedwater Accidents For these accidents, no harsh conditions exist at the transmitter location, so the limiting accident scenario is the post-seismic condition. Per Reference 4.6.6, the total loop uncertainty associated with the comparators that provide the Low Low Steam Generator Level Reactor Trip is computed with the following equation: TLUcomp = +/- 2 xmtr 2 comp 2 xmtr SE TDU norTDU + + + norPME @ 0% Level + MDDPb + ADxmtrBIAS From Section 5.18, MDDPb = +4.88% Span for accident conditions. TLUcomp = +/-1.502 + 1.612 + 1.162+ 1.83 8.38 + 4.88 0.23 TLUcomp = +/- 2.49% Span + 6.71% Span 8.61% Span TLUcomp = + 9.20% Span, 11.10% Span This section shows that the bounding scenario is for the feedwater line break resulting in a harsh environment at the transmitter(s).
RNP-I/INST-1070 Revision 14 Page 82 of 105 7.2.5 Total Loop Uncertainty for use in the EOPs - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, AND 496 Per Reference 4.6.6, the total loop uncertainty associated with the indicator is computed with the following equation. The individual error components, acceopTDUxmtr, TDUisol, TDUind, ATExmtr, and ARExmtr were determined in Sections 6.6.11, 6.8.7, 6.9.9, 6.1.1, and 6.1.3, respectively. TLUind = +/- 2 xmtr 2 xmtr 2 ind 2 isol 2 xmtr ARE ATE TDU TDU accTDU + + + + + IR + acceopPME
+ ADxmtrBIAS TLUind = +/-1.312 + 1.672 + 2.912 + 3.322 + 1.692+ IR + acceopPME 0.23 TLUind = +/- 5.18% Span + IR% Span + acceopPME% Span 0.23% Span Note: The IR value was determined in Section 6.3 and the acceopPME values were determined in Section 6.4.4, and include FVE, DSE and FRE. Also note the IR effects are a positive bias and thus, not included in the negative TLU calculation.
Fluid Height (% Span) Fluid Height (in.) Random Uncertainty (% Span) ADxmtrBIAS Uncertainty (% Span) IR (% Span) Posititve acceopPME (% Span) Negative acceopPME (% Span) 0.00 0.00 +/- 5.18 0.23 2.21 9.52 11.72 16.00 22.96 +/- 5.18 0.23 2.21 8.47 7.94 30.00 43.05 +/- 5.18 0.23 2.21 8.05 9.90 50.00 71.05 +/- 5.18 0.23 2.21 14.08 10.98 75.00 107.63 +/- 5.18 0.23 2.21 20.93 13.26 100.00 143.5 +/- 5.18 0.23 2.21 27.78 15.31 Combined Uncertainties Fluid Height (% Span) Fluid Height (in.) Posititve TLU (% Span) Negative TLU (% Span) 0.00 0.00 16.91 17.13 16.00 22.96 15.86 13.35 30.00 43.05 15.44 15.31 50.00 71.05 21.47 16.39 75.00 107.63 28.32 18.67 100.00 143.5 35.17 20.72
RNP-I/INST-1070 Revision 14 Page 83 of 105 7.3 TOTAL LOOP UNCERTAINTY - POST SEISMIC 7.3.1 Total Loop Uncertainty - High Level Valve Interlock LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 (switch 1) Per Reference 4.6.6, the total loop uncertainty associated with the comparators which provide the High Steam Generator Level Valve interlock is computed with the following equation: TLUcomp = +/- 2 xmtr 2 comp 2 xmtr SE TDU norTDU + + + norPME @ 100% Level + ADxmtrBIAS TLUcomp = +/-1.502 + 1.612 + 1.162+ 0.00 14.01 0.23 TLUcomp = +/- 2.49% Span 14.24% Span TLUcomp = + 2.49% Span, 16.73% Span 7.4 LOOP AS FOUND TOLERANCE 7.4.1 Loop As Found Tolerance - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, & 496 Per Reference 4.6.6, the following equation is used to calculate the indicator Loop As Found Tolerance (LAFTind): LAFTind = +/- 2 ind 2 isol 2 xmtr AFT AFT AFT + + LAFTind = +/-0.742 + 1.202 + 2.442 LAFTind = +/- 2.82% Span 7.4.2 Loop As Found Tolerance - Input to ERFIS Per Reference 4.6.6, the following equation is used to calculate the ERFIS Loop As Found Tolerance (LAFTERFIS): LAFTERFIS = +/- 2 isol 2 isol 2 xmtr AFT AFT AFT + + LAFTERFIS = +/-0.742 + 1.202 + 1.202 LAFTERFIS = +/- 1.85% Span
RNP-I/INST-1070 Revision 14 Page 84 of 105 7.4.3 Loop As Found Tolerance - Comparators LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 LC-474A, 475A, 476A, 484A, 485A, 486A, 494A, 495A, & 496A LC-474B, 475B, 484B, 485B, 494B, & 495B Per Reference 4.6.6, the following equation is used to calculate the comparator Loop As Found Tolerance (LAFTcomp): LAFTcomp = +/- 2 comp 2 xmtr AFT AFT + LAFTcomp = +/-0.742 + 1.162 LAFTcomp = +/- 1.38% Span 7.4.4 Loop As Found Tolerance - Recorder FR-478, 488, & 498 Per Reference 4.6.6, the following equation is used to calculate the recorder Loop As Found Tolerance (LAFTrec): LAFTrec = +/- 2 rec 2 isol 2 xmtr AFT AFT AFT + + LAFTrec = +/-0.742 + 1.202 + 0.592 LAFTrec = +/- 1.53% Span 7.4.5 Loop As Found Tolerance - Input to AMSAC Per Reference 4.6.6, the following equation is used to calculate the Loop As Found Tolerance for AMSAC (LAFTAMSAC): LAFTAMSAC = +/- 2 isol 2 xmtr AFT AFT + LAFTAMSAC = +/-0.742 + 1.202 LAFTAMSAC = +/- 1.41% Span
RNP-I/INST-1070 Revision 14 Page 85 of 105 7.5 GROUP AS FOUND TOLERANCE 7.5.1 Group As Found Tolerance - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, & 496 Per Reference 4.6.6, the following equation is used to calculate the indicator Group As Found Tolerance (GAFTind): GAFTind = +/- 2 ind 2 isol AFT AFT + GAFTind = +/- 2 2 44 .2 20 .1 + GAFTind = +/- 2.72% Span 7.5.2 Group As Found Tolerance - Input to ERFIS Per Reference 4.6.6, the following equation is used to calculate the ERFIS Group As Found Tolerance (GAFTERFIS): GAFTERFIS = +/- 2 isol 2 isol AFT AFT + GAFTERFIS = +/- 2 2 20 .1 20 .1 + GAFTERFIS = +/- 1.70% Span
RNP-I/INST-1070 Revision 14 Page 86 of 105 7.5.3 Group As Found Tolerance - Recorder FR-478, 488, & 498 Per Reference 4.6.6, the following equation is used to calculate the recorder Group As Found Tolerance (GAFTrec): GAFTrec = +/- 2 rec AFT 2 isol AFT + GAFTrec = +/- 2 2 59 .0 20 .1 + GAFTrec = +/- 1.34% Span 7.5.4 Group As Found Tolerance - Comparators LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 LC-474A, 475A, 476A, 484A, 485A, 486A, 494A, 495A, & 496A LC-474B, 475B, 484B, 485B, 494B, & 495B Per Reference 4.6.6, the following equation is used to calculate the comparator Group As Found Tolerance (GAFTcomp): GAFTcomp = +/- AFTcomp GAFTcomp = +/- 1.16% Span 7.5.5 Group As Found Tolerance - Input to AMSAC Per Reference 4.6.6, the following equation is used to calculate the AMSAC Group As Found Tolerance (GAFTAMSAC): GAFTAMSAC = +/- AFTisol GAFTAMSAC = +/- 1.20% Span
RNP-I/INST-1070 Revision 16 Page 87 of 105 8.0 DISCUSSION OF RESULTS High Steam Generator Level Valve Interlock Setpoint - LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 (dual comparator switch 1) The function of this setpoint is to close the main feedwater control valve before the Steam Generator is full of water. Therefore, the High Steam Generator Level interlock setpoint is an increasing setpoint and is computed using negative total loop uncertainties. Per Reference 4.6.6, the following equation is used to calculate the maximum value for this setpoint: SPlimit AL TLU
- where, SPlimit = calculated setpoint limit AL = Analytical Limit TLU = Total Loop Uncertainty Per Section 7.3.1 of this calculation, the negative Total Loop Uncertainty associated with this setpoint is 16.73% Span. Per Section 7.3.1, +/- 2.49% Span of this is the random component.
Per Reference 4.6.6, the random uncertainty may be reduced by applying the single side of interest. Therefore, the random loop uncertainty for this setpoint is +/- 2.05% span (0.8225 2.49% Span). This results in a negative uncertainty of 16.29% Span (2.05% Span 14.24% Span). Per Design Input 5.13, the High Steam Generator Level valve interlock analytical limit is 97% Span. Therefore, SPlimit 97% Span 16.29% Span SPlimit 80.71% Span Per References 4.5.2 through 4.5.10, the High Steam Generator valve interlock setpoint is currently set to 75% Span increasing. The Margin (M) associated with this setpoint is computed as follows: M = SPlimit Calibrated Setpoint M = 80.71% Span 75% Span M = 5.71% Span Therefore, the current High Steam Generator Level valve interlock setpoint is conservative. Rev. 16
RNP-I/INST-1070 Revision 16 Page 88 of 105 For a rising setpoint, the Allowable Value (AV) is determined using the following equation: AV = SP + GAFT (Eq. 29 - Ref. 4.6.6 // FAD-EG-ALL-1153, Section 5.3.2.4) Where: SP* = Hi SG Level Valve Interlock calibrated setpoint (= 75% span). GAFT* = Calculated Group As Found Tolerance (= 1.16 % - Section 7.5.4 of this calc). Thus, AV = 75% span + 1.16% span AV*** = 76.16% span Therefore, to ensure channel operability and protection of the analytical limit (AL) assumed in the safety analysis, the surveillance measured setpoint should be < 76.16% span. Note:
- SP is the actual setpoint at which the trip action occurs and, for increasing setpoints, can be conservatively set at a lower value than SPlim = AL + TLU.
** The GAFT is determined using vendor specification/bounding values of calibration tolerance, device dift and test equipment measurement uncertainty. *** AV by definition is a limit (acceptance criterion), which the surveillance measured setpoint should be maintained within to ensure operability of the channel.
The Loop As Found Tolerance (LAFT) of 1.38% Span is computed in Section 7.4.3. Per Reference 4.6.6, the Channel Operability Limit (COL) is computed with the following equation: COL = SP + LAFT, where SP = calibrated setpoint COL = 75% Span + 1.38% Span COL = 76.38% Span 97.0% Analytic Limit (AL) LAFT = 1.3 8 % 76.38% 76.16% GAFT = 1.1 6 % 75.0% (variable) Nominal NOTE: All SG levels are in % span. Not Drawn to Scale Operating Margin (variable) Additional Margin (M=5.7 1 %) Total Loop Uncertainty (TLU=1 6.2 9 %) High Steam Generator Level Valve Interlock Setpoint Diagram Channnel Operability Limit (COL) Allowable Value (AV) Calibrated Setpoint (SP ) Total Allowance = TLU + M Rev. 16
RNP-I/INST-1070 Revision 14 Page 89 of 105 High Steam Generator Level Alarm Setpoint - LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 (switch 2) The function of this setpoint is to warn the operator that Steam Generator Level is approaching the valve interlock setpoint which closes the feedwater control valves. Therefore, the High Steam Generator Level alarm setpoint is an increasing setpoint and is computed using negative total loop uncertainties. Per Reference 4.6.6, the following equation is used to calculate the maximum value for this setpoint: SPlimit AL TLU
- where, SPlimit = calculated setpoint limit AL = Analytical Limit TLU = Total Loop Uncertainty The function of this alarm is to warn the operator before the feedwater control valves are closed by the High Steam Generator Level valve interlock, and this alarm is provided by the same dual bistable module that provides the valve interlock. Any uncertainty at the input of the bistable module will offset both the interlock and alarm setpoints in the same direction. Therefore, the only uncertainties which need to be considered for this setpoint are those associated with the bistable which provides the valve interlock and the bistable which provides the alarm.
Therefore, the total uncertainty associated with this setpoint is the square root sum of squares of two bistable uncertainty terms. Per Section 6.7.7, the uncertainty associated with one bistable is +/- 1.61% Span. Therefore, the total uncertainty associated with this setpoint is 2.28% Span (negative portion of the SRSS of two +/- 1.61% Span terms). Per Design Input 5.15, the High Steam Generator Level alarm setpoint limit is 75% Span. Therefore, SPlimit 75% Span 2.28% Span SPlimit 72.72% Span Per References 4.5.2 through 4.510, the High Steam Generator valve interlock setpoint is currently set to 60% Span increasing. The Margin (M) associated with this setpoint is computed as follows: M = SPlimit Calibrated Setpoint M = 72.72% Span 60% Span M = 12.72% Span Therefore, the current High Steam Generator Level alarm setpoint is conservative.
RNP-I/INST-1070 Revision 14 Page 90 of 105 Low Steam Generator Level Alarm Setpoint - LC-474B, 475B, 484B, 485B, 494B, & 495B The function of this setpoint is to provide an alarm when Steam Generator level is approaching the Low Steam Generator Level Reactor Trip setpoint. Therefore, the Low Steam Generator level alarm is a decreasing setpoint and is computed using positive total loop uncertainties. Per Reference 4.6.6, the following equation is used to calculate the minimum value for this setpoint: SPlimit AL + TLU
- where, SPlimit = calculated setpoint limit AL = Analytical Limit TLU = Total Loop Uncertainty Per Section 7.1.6 of this calculation, the positive Total Loop Uncertainty associated with this setpoint is 2.20% Span. Per Design Input 5.16, the Low Steam Generator Level alarm setpoint limit is 30% Span. Therefore, SPlimit 30% Span + 2.20% Span SPlimit 32.20% Span Per References 4.5.2 through 4.5.10, the Low Steam Generator Level alarm setpoint is currently set to 35% Span decreasing. The Margin (M) associated with this setpoint is computed as follows:
M = Calibrated Setpoint SPlimit M = 35% Span 32.20% Span M = 2.80% Span Therefore, the current alarm setpoint is conservative.
RNP-I/INST-1070 Revision 14 Page 91 of 105 Per Section 7.5.4 of this calculation, the Group As Found Tolerance (GAFT) is 1.16% Span. Per Reference 4.6.6, the Allowable Value (AV) associated with this setpoint is computed as follows: AV SP GAFT, where SP = calibrated setpoint AV 30% Span 1.16% Span AV 28.84% Span The Loop As Found Tolerance (LAFT) of 1.38% Span is computed in Section 7.4.3. Per Reference 4.6.6, the Channel Operability Limit (COL) is computed with the following equation: COL = SP LAFT, where SP = calibrated setpoint COL = 30% Span 1.38% Span COL = 28.62% Span
RNP-I/INST-1070 Revision 14 Page 92 of 105 Low Low Steam Generator Level Alarm Setpoint - LC-474A, 475A, 476A, 484A, 485A, 486A, 494A, 495A, & 496A (dual comparator switch 2) The function of this setpoint is to provide an alarm when Steam Generator level is approaching the Low Low Steam Generator Level Reactor Trip setpoint. Therefore, the Low Low Steam Generator level alarm is a decreasing setpoint and is computed using positive total loop uncertainties. Per Reference 4.6.6, the following equation is used to calculate the minimum value for this setpoint: SPlimit AL + TLU
- where, SPlimit = calculated setpoint limit AL = Analytical Limit TLU = Total Loop Uncertainty Per Section 7.1.5 of this calculation, the positive Total Loop Uncertainty associated with this setpoint is 3.26% Span. Per Design Input 5.17, Low Low Steam Generator Level alarm setpoint limit is 16% Span. Therefore, SPlimit 16% Span + 3.26% Span SPlimit 19.26% Span Per Reference 4.5.2-10, the Low Low Steam Generator Level Alarm setpoint is currently set to 35% Span decreasing. The Margin (M) associated with this setpoint is computed as follows:
M = Calibrated Setpoint SPlimit M = 35% Span 19.26% Span M = 15.74% Span Therefore, the current alarm setpoint is conservative.
RNP-I/INST-1070 Revision 16 Page 93 of 105 Low Low Steam Generator Level Reactor Trip Setpoint - LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 The function of this setpoint is to provide a Reactor Trip before Steam Generator level falls below the Low Low Steam Generator analytical limit. Therefore, the Low Low Steam Generator Reactor Trip setpoint is a decreasing setpoint and is computed using positive total loop uncertainties. Per Reference 4.6.6, the following equation is used to calculate the minimum value for this setpoint: SPlimit AL + TLU
- where, SPlimit = calculated setpoint limit AL = Analytical Limit TLU = Total Loop Uncertainty Per Section 7.2.4 of this calculation, the random portion of the Total Loop Uncertainty associated with this setpoint is +/-3.92% Span, and the positive bias portion under accident conditions is +8.00% Span. Per Reference 4.6.6, the random loop uncertainty may be reduced by applying the single side of interest. Therefore, the random loop uncertainty for this setpoint is +/-3.22% Span (3.92% Span 0.8225). Therefore, the positive total loop uncertainty associated with this setpoint is 11.22% Span.
Per Reference 4.7.3, Table 2, the Low Low Steam Generator Level Reactor Trip setpoint analytical limit is 0% Span. Therefore, SPlimit 0% Span + 11.22% Span SPlimit 11.22% Span Per Reference 4.7.2, Table 3.3.1-1, Item 13, the Low Low Steam Generator Level Reactor Trip setpoint is currently set to 16% Span decreasing. The Margin (M) associated with this setpoint is computed as follows: M = Calibrated Setpoint SPlimit M = 16% Span - 11.22% Span M = 4.78% Span Rev. 16
RNP-I/INST-1070 Revision 16 Page 94 of 105 Per Reference 4.6.6, the Allowable Value (AV) associated with Low-Low Steam Generator Level Reactor Trip Setpoint (falling setpoint) is computed as follows: AV = SP GAFT (Eq. 30 - Ref. 4.6.6 // FAD-EG-ALL-1153, Section 5.3.2.4) Where SP = Low-Low SG Level Calibrated Trip Setpoint (= 16% span//Ref. 4.7.2, Table 3.3.1-1, Item 13) GAFT = Calculated Group As Found Tolerance (= 1.16% span - Section 7.5.4 of calc). Thus, AV = 16% Span 1.16% Span
- AV = 14.84% Span Therefore, to ensure channel operability and protection of the analytical limit (AL) assumed in the safety analysis, the surveillance measured setpoint should be > 14.84% span.
- Note: The plant, however, has conservatively implemented AV = 15.36% span (Reference 4.7.2, RPS Instrumentation, Table 3.3.1-1, Item 13).
The Loop As Found Tolerance (LAFT) of 1.38% Span is computed in Section 7.4.3. Per Reference 4.6.6, the Channel Operability Limit (COL) is computed with the following equation: COL = SP LAFT, where SP = calibrated setpoint COL = 16% Span 1.38% Span COL = 14.62% Span Allowable Value ( 14.84% Span) Additional Margin (4.78% Span) Total Loop Uncertainty (11.22% Span) Analytical Limit (0% Span) Setpoint (16% Span decreasing) Operating Margin (variable) Normal (variable) Group As Found Tolerance (1.16% Span) Loop As Found Tolerance (1.38% Span) Channel Operability Limit (14.62% Span) Low Low Steam Generator Level Reactor Trip Setpoint Diagram Rev. 16 Rev. 16 I I I
RNP-I/INST-1070 Revision 14 Page 95 of 105 8.1 Impact On Improved Technical Specifications Based on the results of this calculation, there is no impact to the Technical Specifications. 8.2 Impact On Ufsar Revision 13 of RNP-I/INST-1070 does not impact the UFSAR. 8.3 Impact On Design Basis Documents This calculation impacts no design basis documents. 8.4 Impact On Other Calculations Revision 13 of this calculation does not impact other calculations. This calculation, revision 12, impacts the following calculations:
- 1. RNP-I/INST-1103
- The instrument uncertainty values used in RNP-I/INST-1103 Rev. 6 (Reference 4.2.4) references this calculation. Due to changes in total loop uncertainties and the revised IR value, calculations for various EOP setpoints within RNP-I/INST-1103 Rev. 6 require change.
- 2. RNP-I/INST-1079
- RNP-I/INST-1079 Rev. 4 (Reference 4.2.9) references this calculation but no AOP setpoints are affected by this revision.
- 3. RNP-M/MECH-1651
- RNP-M/MECH-1651 Rev. 16 (Reference 4.2.3) references this calculation. Due to changes in steam generator water level uncertainty, parameter 14 in Table I of RNP-M/MECH-1651 requires update to revise the TLU from 3.99% to 3.80%.
In addition, calculations RNP-I/INST-1132 and RNP-I/INST-1071 reference this calculation, but are not impacted by the changes made in this revision. Note that RNP-I/INST-1071 is identified as an impacted document by EC 413069, but this is due to the replacement of recorder LR-477. The changes made to RNP-I/INST-1070 under this revision for the replacement of recorders FR-478, FR-488 and FR-498 do not impact RNP-I/INST-1071.
RNP-I/INST-1070 Revision 14 Page 96 of 105 8.5 Impact On Plant Procedures The following procedures reference this calculation, although none are directly affected by this revision: PIC-005, Steam Generator A Narrow Range Level Transmitter LT-474 Calibration, Revision 13 (Reference 4.5.1) PIC-005-1, Steam Generator A Narrow Range Level Transmitter LT-475 Calibration, Revision 0 (Reference 4.5.14) PIC-005-2, Steam Generator A Narrow Range Level Transmitter LT-476 Calibration, Revision 0 (Reference 4.5.15) PIC-005-4, Steam Generator B Narrow Range Level Transmitter LT-484 Calibration, Revision 0 (Reference 4.5.16) PIC-005-5, Steam Generator B Narrow Range Level Transmitter LT-485 Calibration, Revision 0 (Reference 4.5.17) PIC-005-6, Steam Generator B Narrow Range Level Transmitter LT-486 Calibration, Revision 0 (Reference 4.5.18) PIC-005-8, Steam Generator C Narrow Range Level Transmitter LT-494 Calibration, Revision 0 (Reference 4.5.19) PIC-005-9, Steam Generator C Narrow Range Level Transmitter LT-495 Calibration, Revision 1 (Reference 4.5.20) PIC-005-10, Steam Generator C Narrow Range Level Transmitter LT-96 Calibration, Revision 0 (Reference 4.5.21) LP-027, Steam Generator #1 Narrow Range (N/R) Level Channel 476, Revision 16 (Reference 4.5.2) LP-028, Steam Generator #2 Narrow Range (N/R) Level Channel 486, Revision 15 (Reference 4.5.3) LP-029, Steam Generator #3 Narrow Range (N/R) Level Channel 496, Revision 19 (Reference 4.5.4) LP-030, Steam Generator #1 Narrow Range (N/R) Level Channel 474, Revision 15 (Reference 4.5.5) LP-031, Steam Generator #2 Narrow Range (N/R) Level Channel 484, Revision 15 (Reference 4.5.6) LP-032, Steam Generator #3 Narrow Range (N/R) Level Channel 494, Revision 13 (Reference 4.5.7) LP-033, Steam Generator #1 Narrow Range (N/R) Level Channel 475, Revision 13 (Reference 4.5.8) LP-034, Steam Generator #2 Narrow Range (N/R) Level Channel 485, Revision 16 (Reference 4.5.9) LP-035, Steam Generator #3 Narrow Range (N/R) Level Channel 495, Revision 13 (Reference 4.5.10) PIC-844, Yokogawa Recorders, Revision 13 (Reference 4.5.12)
RNP-I/INST-1070 Revision 14 Page 97 of 105 9.0 SCALING CALCULATIONS 9.1 Level Transmitter (LT-474, 475, 476, 484, 485, 486, 494, 495, and 496) Per EDB, each transmitter is a Rosemount model 3154ND2R2F1E7 differential pressure transmitter. Per Reference 4.4.3, a range code 2 transmitter has the following differential pressure ranges 0-25 to 0-250 inwc. Per Reference 4.7.9, the Steam Generator pressure at 100% load is approximately 800 psia, and the pressure at 0% load is approximately 1020 psia. Per Reference 4.7.5, the Steam Generator temperature at 800 psia is 518°F, and the temperature at 1020 psia is 547°F. Per Reference 4.1.15, the distance between the upper and lower instrument taps is 143 inches. Per Reference 4.1.14, the Steam Generator is constructed from SA-302 Grade B Plate. This material is defined in Reference 4.7.8 as manganese-molybdenum. Per Reference 4.7.7, the average coefficient of thermal expansion for this material between 500°F and 550°F is 7.73x10-6 in / in / °F. The following equation is used to compute the thermal expansion of the Steam Generator during normal operation (100% load): Hoperating = Hcold [ 1 + (Toperating - Tcold)] Hoperating = 143 inches [ 1 + 7.73x10-6(518 °F - 70 °F)] Hoperating = 143.5 inches As stated above, the normal operating pressure range of the Steam Generator is 800 psia (100% load) and 1020 psia (0% load). Therefore, the transmitters are scaled for a process fluid of compressed water at 900 psia @500°F and saturated steam at 900 psia. The reference leg contains compressed water at a nominal temperature of 120°F. The following equation is used to obtain the calibration values for the transmitter: PC = ( ) RC SC WC SG H SG h H SG h
+
- where, h = height of fluid (inches)
H = height of measured level span = 143.5 inches SGWC = specific gravity of fluid = 0.787341 @ 900 psia, 500°F SGSC = specific gravity of steam = 0.032034 @ 900 psia, saturated SGRC = specific gravity of reference leg fill fluid = 0.992946 @ 900 psia, 120°F, compressed
RNP-I/INST-1070 Revision 14 Page 98 of 105 Therefore, Transmitter Calibration Points Per Reference 4.4.3, a static pressure span effect of 0.75% of input per 1000 psi is specified. This effect is calibrated out by adjusting the calibrated range of the transmitter as follows:
psi 1000 psi 900 input of 75 .0 = 0.675% of input For zero percent level, 0.675% (-138 inwc / 100%) = -0.932 inwc -0.932 inwc (100% Span / 108 inwc) = -0.863% Span -0.863% Span (16 mA / 100% Span) = -0.138 mA 4.000 mA - 0.138 mA = 3.862 mA For 100 percent level, 0.675% (-30 inwc / 100%) = -0.203 inwc -0.203 inwc (100% Span / 108 inwc) = -0.188% Span -0.188% Span (16 mA / 100% Span) = -0.030 mA 20.000 mA - 0.030 mA = 19.970 mA Therefore, the transmitters are calibrated from -138 to -30 inwc (3.862 mA to 19.970 mA) which corresponds to -137.1 to -29.8 inwc (4 to 20 mA) at zero pressure. At the operating pressure, the span of each loop is 108 inwc. Fluid Height (% Span) Fluid Height (in) Calibrated PC (inwc) 0.00% 0.00 -138 16.00% 22.96 -121 30.00% 43.05 -105 50.00% 71.75 -84 75.00% 107.63 -57 100.00% 143.50 -30
RNP-I/INST-1070 Revision 14 Page 99 of 105 The following equation is used to compute the required transmitter output for a given differential pressure input: EO = ( ) Vdc 000 .1 P inwc 1. 137 inwc 107.3 Vdc 4 +
Per Section 6.6.12 of this calculation, the As Found Tolerance (AFT) of the transmitter is +/- 0.76% Span. Per Section 6.6.13 of this calculation, the As Left Tolerance (ALT) of the transmitter is +/- 0.50% Span. The AFT and ALT are converted to voltage units with the following equations: AFT(Vdc) = +/-4 Vdc
100 Span) (% AFT = +/-4 Vdc( 0.74% 100 )= +/- 0.030 Vdc ALT(Vdc) = +/-4 Vdc
100 Span) (% ALT = +/-4 Vdc
100 Span 50 .0 = +/- 0.020 Vdc The calibration table for the transmitter is as follows: Required Input (inwc) Desired Output (Vdc) As Found Tolerance (Vdc) As Left Tolerance (Vdc) 137.1 1.000 0.970 to 1.030 0.980 to 1.020 110.3 2.000 1.970 to 2.030 1.980 to 2.020 83.5 3.000 2.970 to 3.030 2.980 to 3.020 56.6 4.000 3.970 to 4.030 3.980 to 4.020 29.8 5.000 4.970 to 5.030 4.980 to 5.020 Transmitter Calibration Table
RNP-I/INST-1070 Revision 14 Page 100 of 105 9.2 Isolator Module (LM-474, 474A, 474B, 475, 475A, 476, 476A, 484, 484A, 485, 485A, 485B, 486, 486A, 494, 494A, 494B, 495, 495A, 496, 496A, And 496B) The isolator transfer function is as follows: EO = EI Per Section 6.8.8 of this calculation, the As Found Tolerance (AFT) of the isolator is +/- 1.20% Span. Per Section 6.8.9 of this calculation, the As Left Tolerance (ALT) of the isolator is +/- 0.50% Span. The AFT and ALT are converted to voltage units with the following equations: AFT(Vdc) = +/-4 Vdc
100 Span) (% AFT = +/-4 Vdc
100 Span 20 .1 = +/- 0.048 Vdc ALT(Vdc) = +/-4 Vdc
100 Span) (% ALT = +/-4 Vdc
100 Span 50 .0 = +/- 0.020 Vdc The calibration table for the isolator is as follows: Required Input (Vdc) Desired Output (Vdc) As Found Tolerance (Vdc) As Left Tolerance (Vdc) 1.000 1.000 0.952 to 1.048 0.980 to 1.020 2.000 2.000 1.952 to 2.048 1.980 to 2.020 3.000 3.000 2.952 to 3.048 2.980 to 3.020 4.000 4.000 3.952 to 4.048 3.980 to 4.020 5.000 5.000 4.952 to 5.048 4.980 to 5.020 Isolator Calibration Table
RNP-I/INST-1070 Revision 14 Page 101 of 105 9.3 Comparator Module (LC-474, 475, 476, 484, 485, 486, 494, 495, And 496) Each comparator provides a High Steam Generator Level alarm (switch 2), and a High Steam Generator Level interlock (switch 1). The following equation is used to compute the voltage representation of the comparator setpoints: Setpoint(Vdc) = Vdc 000 .1 100% (%) Setpoint Vdc 4 +
Per Section 8.0 of this calculation, the High Steam Generator Level alarm setpoint is 60% increasing, and the High Steam Generator Level valve interlock setpoint is 75% increasing. Therefore, the setpoints expressed in voltage units are 3.400 Vdc (60%) and 4.000 Vdc (75%). Per Section 6.7.8 of this calculation, the As Found Tolerance (AFT) of the comparator is +/- 1.16% Span. Per Section 6.7.9 of this calculation, the As Left Tolerance (ALT) of the comparator is +/- 0.50% Span. The AFT and ALT are converted to voltage units with the following equations: AFT(Vdc) = +/-4 Vdc
100 Span) (% AFT = +/-4 Vdc
100 Span 16 .1 = +/- 0.046 Vdc ALT(Vdc) = +/-4 Vdc
100 Span) (% ALT = +/-4 Vdc
100 Span 50 .0 = +/- 0.020 Vdc The following table provides calibration values for the comparators: Setpoint (%) Setpoint (Vdc) As Found Tolerance (Vdc) As Left Tolerance (Vdc) 75 4.000 3.954 to 4.046 3.980 to 4.020 60 3.400 3.354 to 3.446 3.380 to 3.420 Comparator Calibration Table
RNP-I/INST-1070 Revision 14 Page 102 of 105 9.4 Comparator Module (LC-474A, 475A, 476A, 484A, 485A, 486A, 494A, 495A, and 496A) Each comparator provides a Low Low Steam Generator Level alarm (switch 2), and a Low Low Steam Generator Level Reactor Trip (switch 1). The following equation is used to compute the voltage representation of the comparator setpoints: Setpoint(Vdc) = Vdc 000 .1 100% (%) Setpoint Vdc 4 +
Per Section 8.0 of this calculation, the Low Low Steam Generator Level Reactor Trip setpoint is 16% decreasing, and the Low Low Steam Generator Level alarm setpoint is 35% decreasing. Therefore, the setpoints expressed in voltage units are 1.64 Vdc (16%) and 2.400 Vdc (35%). Per Section 6.7.8 of this calculation, the As Found Tolerance (AFT) of the comparator is +/- 1.16% Span. Per Section 6.7.9 of this calculation, the As Left Tolerance (ALT) of the comparator is +/- 0.50% Span. The AFT and ALT are converted to voltage units with the following equations: AFT(Vdc) = +/-4 Vdc
100 Span) (% AFT = +/-4 Vdc
100 Span 16 .1 = +/- 0.046 Vdc ALT(Vdc) = +/-4 Vdc
100 Span) (% ALT = +/-4 Vdc
100 Span 50 .0 = +/- 0.020 Vdc The following table provides calibration values for the comparators: Setpoint (%) Setpoint (Vdc) As Found Tolerance (Vdc) As Left Tolerance (Vdc) 35 2.400 2.354 to 2.446 2.380 to 2.420 16 1.640 1.594 to 1.686 1.620 to 1.660 Comparator Calibration Table
RNP-I/INST-1070 Revision 14 Page 103 of 105 9.5 Comparator Module (LC-474B, 475B, 484B, 485B, 494B, And 495B) Each comparator provides a Low Steam Generator Level alarm. The following equation is used to compute the voltage representation of the comparator setpoints: Setpoint(Vdc) = Vdc 000 .1 100% (%) Setpoint Vdc 4 +
Per Section 8.0 of this calculation, the Low Steam Generator Level alarm setpoint is 35% decreasing. Therefore, the setpoint expressed in voltage units is 2.400 Vdc (35%). Per Section 6.7.8 of this calculation, the As Found Tolerance (AFT) of the comparator is +/- 1.16% Span. Per Section 6.7.9 of this calculation, the As Left Tolerance (ALT) of the comparator is +/- 0.50% Span. The AFT and ALT are converted to voltage units with the following equations: AFT(Vdc) = +/-4 Vdc
100 Span) (% AFT = +/-4 Vdc
100 Span 16 .1 = +/- 0.046 Vdc ALT(Vdc) = +/-4 Vdc
100 Span) (% ALT = +/-4 Vdc
100 Span 50 .0 = +/- 0.020 Vdc The following table provides calibration values for the comparators: Setpoint (%) Setpoint (Vdc) As Found Tolerance (Vdc) As Left Tolerance (Vdc) 35 2.400 2.354 to 2.446 2.380 to 2.420 Comparator Calibration Table
RNP-I/INST-1070 Revision 14 Page 104 of 105 9.6 Indicator (LI-474, 475, 476, 484, 485, 486, 494, 495, And 496) The indicators are scaled to provide an output of 0 to 100% for a 1 to 5 Vdc input. Therefore, the transfer function for the indicator is as follows: IO = ( ) Vdc 000 .1 E Vdc 4 100% I
Per Section 6.9.10 of this calculation, the As Found Tolerance (AFT) of the indicator is +/- 2.44% Span. Per Section 6.9.11 of this calculation, the As Left Tolerance (ALT) of the indicator is +/- 2.00% Span. The AFT and ALT are converted to voltage units with the following equations: AFT(Vdc) = +/-4 Vdc
100 Span) (% AFT = +/-4 Vdc
100 Span 44 .2 = +/- 0.098 Vdc ALT(Vdc) = +/-4 Vdc
100 Span) (% ALT = +/-4 Vdc
100 Span 00 .2 = +/- 0.080 Vdc The following table provides calibration values for the indicators: Desired Input (Vdc) Required Output (%) As Found Tolerance (Vdc) As Left Tolerance (Vdc) 1.000 0 0.902 to 1.098 0.920 to 1.080 2.000 25 1.902 to 2.098 1.920 to 2.080 3.000 50 2.902 to 3.098 2.920 to 3.080 4.000 75 3.902 to 4.098 3.920 to 4.080 5.000 100 4.902 to 5.098 4.920 to 5.080 Indicator Calibration Table
RNP-I/INST-1070 Revision 14 Page 105 of 105 9.7 Recorder (FR-478, 488, & 498) The recorders are scaled to provide an output of 0 to 100% for a 1 to 5 Vdc input. Therefore, the transfer function for the recorder is as follows: RO = ( ) Vdc 000 .1 E Vdc 4 100% I
Per Section 6.10.9 of this calculation, the As Found Tolerance (AFT) of the recorder is +/- 0.59% Span. Per Section 6.10.10 of this calculation, the As Left Tolerance (ALT) of the recorder is +/- 0.50% Span. The AFT and ALT are converted to voltage units with the following equations: AFT(Vdc) = +/- 4 Vdc
100 Span) (% AFT = +/- 4 Vdc
100 Span 0.59% = +/- 0.024 Vdc ALT(Vdc) = +/- 4 Vdc
100 Span) (% ALT = +/- 4 Vdc
100 Span 0.50% = +/- 0.020 Vdc The following table provides calibration values for the recorder: Desired Input (Vdc) Required Output (%) As Found Tolerance (Vdc) As Left Tolerance (Vdc) 1.000 0 0.976 to 1.024 0.980 to 1.020 2.000 25 1.976 to 2.024 1.980 to 2.020 3.000 50 2.976 to 3.024 2.980 to 3.020 4.000 75 3.976 to 4.024 3.980 to 4.020 5.000 100 4.976 to 5.024 4.980 to 5.020 Recorder Calibration Table
RNP-I/INST-1070 Revision 3 ATTACHMENT B Page 1 of 1 COMPARATOR DRIFT c:.u.DU1'ICII 11&%& SID'1' UVIIII' saran BACAii NDDZL 118 SISIZ CDG'AL\\%01. TC*l41 LC*949 PC*l45A l'C* 143 Cal. Dt. Devia. Cal. Dt. Devia. Cal. De. Devia. Cd. Dt. DeYia. 7/14/84 9/26/84 .S/29/14 .001 .001 9/2.S/8.5 .000 6/26/8.5 .001 .008 6/04/86 9/24/86 2/23,. 2/02/16 .001 .002 .004 .001 .5/1.5/87 9/28/87 4/30/87 llD/87 .003 .002 .009 .003 6/13/88 9/30/88 12/29/88 21'5118 .003 11/20/89 .001 .009 71'41'19 2/26/90 9/22/90 BACAK NDmL 118 DUAL COHPALU'OI LC* 106A LC*l061 U:*108A LC*l0H Cal.De. Devia. Devia. Devia. 6/14/84 .000 .000 .001 4/01/8.5 .001 .000 .001 4/18/86 .001 .001 .001 3/03/87 .001 .003 .001 4/06/88 .000 .001 .002 4/04/89 .000 .000 4/04/90 Instnaent lfalf1111ction H/A
- ot Available Devia. Devia. Devia. Devia. Devia.
.004 .ooo .000 .000 .000 .001 .001 .000 -A
- tA
.000 .001 .000 -A I/A .001 .000 .001 -A
- tA
.000 .002 .001 -A.,. .003 .003 Maximum deviation noted between the aa*foad and as-left nlues recorded on the available calibration data sbeets vas.009 vdc. This value is apprOlliaately equal ta 0.2.5%.
RNP-I/INST-1070 Revision 3 ATTACHMENT C Page 1 of 1 ROSEMOUNT DRIFT I ROSEIIOUNT Sepeamber 20, 1990 Entergy Operations .:.;nrro .:.nasYUCal Grand Gulf Nuclear Plant ESC Building P.O. Box 429 Port Gibson, MS 39150 Attention: Bob McCain
Dear Mr. McCain:
"-Mine. T 2001 ~ K:0:ftOIOqY Omtt ECIIIII P,a,ne. MN 5534, Tt111121 9'1-65111 T-* 4310012 Fas u512l 52-Rosemount has developed a new drift specification for the Model 1152, llSJ and 1154 pressure transmitters. The specification is +/-.2t ORL over a 30 month period. In addition, all normal performance specs (i.e. accuracy) can be considered 3 sigma specs. The nuclear specs such as LOCA/HELB, radiation, and seismic were developed based on type testing. Due to the S111all sample size of test units, it is difficult tc apply statistical methodology to these type of specs. If you have any further questions please feel free tc call me at (612) 828-3100. NPL:lbc Enc: PCS 2302, 2388, 2514, 2235 Report D8600063 c: Les Callender #2
RNP-I/INST-1070 Revision 3 ATTACHMENT D Page 1 of 1 INTERNATIONAL INSTRUMENTS INDICATOR DATA www***...,,w-Gilfw"el F I W WWW
- -* did... lsQU::.,V*-
Tea di &L~& --TacMN0LCJQY.II\\C.*T_,.__......_... _Q...., ___......,-.CT-=-471 T*aao:11*1*9'7111 TWJC: 710-*!Sa-30911 IIAJC: cao:11.., -"37 Jun* 24, 1991 CAROLINA POWER* LIGHT P.O. Box 1~1 Raleigh, NC 27602-1"1 Attn: Robert l'!Ann CliS 6th Floor Per our canv.,.S&tian the drift -,d T.C. for lnt. r-nat.lanal lnst.r-want.s aadel 2S20 are 1% a-f span per year and
- 1%
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RNP-I/INST-1070 Revision 11 ATTACHMENT F Page 1 of 2 NUS Instruments Long Term Drift Test for NUS Modules - Final Report, Executive October 26, 2001 Pat Hartig FirstEnergy Nuclear Operating Company Beaver Valley Power Station P.O.Box 4 Shippingport, Pa 15077
Subject:
Long Term Drift Test (LTDT) Results for NUS modules - Final Report, Executive Summary
Dear Mr. Pat Hartig:
NUS Instruments (NUSI), undertook a research and development project in 1996 to re-engineer instrumentation for use as replacements for the obsolete Hagan line of nuclear plant instrumentation. The NUSI replacement modules were designed originally using specifications written by Public Service Electric and Gas (PSE&G). The final specifications incorporated both original Hagan published specifications and new or additional plant-specific requirements. The final agreed upon specification formed the design basis for the NUS Instruments 800 Series product line that has been sold to many nuclear plants including Salem, H.B. Robinson, Turkey Point and Diablo Canyon. NUSI has been requested by FENOC to supply instrumentation drift specifications for the 800 Series modules. We understand that these numbers are to be used to determine requirements for plant calibration cycles for these modules. The calibration cycle may be extended if it can be shown that the drift of the replacement modules is below specified criteria. This change would result in a significant savings in plant maintenance costs. NUSI was contracted by PSE&G to conduct a 36-month Long Term Drift Test (LTDT). This test was conducted on four classes of modules with four units of each type for a total of sixteen modules undergoing the test. The four classes of modules consisted of four Dual Alarm Modules (DAM), four One-channel Analog Isolators (OCA), four RTD Amplifiers (RTD), and four Four-Channel Summing Modules (SUM). A loop of instruments was also tested to determine overall loop drift. 440 West Broadway, Idaho Falls, ID 83402, Phone: 208-529-1000, Fax: 208-524-9238 NUS Instruments
RNP-I/INST-1070 Revision 11 ATTACHMENT F Page 2 of 2 Drift was specified as a percentage of the upper range limit (URL) over an 18-month period. After 36 months of testing, NUSI can proudly state that all modules performed better than the stated specification. The specification and summary results are given below. SPECIFICATION TEST RESULTS MODULE CLASS ACCURACY DRIFT DRIFT (%URL) 2 sigma DRIFT RTD 0.5% 0.4% 0.240 % 0.365 % OCA 0.5% 0.2% 0.048 % 0.074 % DAM 0.5% 0.3% 0.083 % 0.127 % SUM 0.5% 0.6% 0.135 % 0.214 % LOOP 0.5% Not specified 0.115 % 0.186 % NUSI is currently in the process of preparing the final test report which will provide greater details about the test modules and fixture, test procedure and processes, data and sampling intervals, analysis and plots showing the data trends. This data represents over 26,000 hours of testing and over 24,000 individual data measurements. NUSI can make available upon request the Excel 97 workbook that provides the data, analysis, and necessary graphing tools. This report will be available October 31, 2001. It is also worth noting that several utilities have been conducting their own independent long term drift tests of a instruments installed in their loops. They can independently support that the NUSI 800 Series instruments meet or exceed the long term drift specification. Please contact NUS Instruments for additional information. SCIENTECH, Inc., NUS Instruments 440 West Broadway Idaho Falls, Idaho 83402 (208) 529-1000 (LaWanda Wold or Heath Buckland) Respectfully, LaWanda Wold Facility Manager, NUS Instruments Office Address: SCIENTECH - Broadway 440 West Broadway Idaho Falls, Idaho 83402-3638 208.524.9200 Front Desk 208.524.9282 Fax Work Phone: 208.524.9236 Facsimile: 208.524.9238 E-mail: LWold@scientech.com
RNP-I/INST-1070 Revision 11 ATTACHMENT G Page 1 of 2 Email from NUS Confirming Similarity of NUS Isolator Modules, dated 01/15/02 From: James Siedelmann@scientech.com Sent: Tuesday, January 15,2002 11:54 AM To: bobh@hursttech.com Subj.: Series SC993 and Series 800 Isolators Series SC993 isolators were manufactured by us under the names of Energy Incorporated, EI Electronics, EI Systems and EI International. They are an early version of stand alone isolator intended for electrical isolation of the inputs from the outputs. They were encapsulated and had terminal blocks for connection of power, inputs and outputs. They were single channel devices. The power supply used was an early type of switching power supply that is no longer manufactured. The isolation circuitry was basically the same as is currently used in all NUSI isolators and many of our other instrumentation devices. The actual isolation element, the Burr-Brown 3656 is identical to that used today. All devices manufactured then underwent dielectric withstand testing of 3000 Vdc and at 2500 Vac to ensure their readiness to isolate a potential fault. They also were 100% functional tested. The units were encapsulated with an epoxy and aluminum oxide based compound that made them impervious to virtually all environmental concerns and seismically were considered a "brick". They were qualified simply by their mounting constraints. Internal heating was not a concern as the potting compound used had a very high thermal conductivity. Outputs and power were fused on the top surface of the aluminum chassis. Span and zero adjustments were also mounted there. The device is simple internally and externally. It has many years of reliable performance at several nuclear plants with little or no undue maintenance issues. The only know life issue is the power supplies used (then and now) have aluminum electrolytic capacitors with know life characteristics of about twenty years. Pots should not be adjusted unless the unit is out of tolerance to reduce the wear and tear on them. If a typical maintenance cycle is used, the devices will easily achieve their twenty year life expectancy with no problems. The limited life characteristics will not affect their isolation specifications in any way. These devices had only limited surge protection circuitry (on the inputs) included. Outputs and power ports may be susceptible to damage from surges but will not pass this to the inputs. NUS Instruments currently manufactures devices that are form, fit and function replacements for the SC993 series. These are the SCA101 devices in the SCA100 series of isolators. These devices differ from the SC993 in the power supply used and that the chassis is 1/16" deeper than the older versions. These devices have surge suppression circuitry and have been surge tested on all ports. Fault testing and other isolation parameter testing has been completed on these devices. All other parameters, including the circuitry and elements used do not differ from the SC993 series.
RNP-I/INST-1070 Revision 11 ATTACHMENT G Page 2 of 2 Series 800 devices were manufactured by us under the names Haliburton NUS, Haliburton NUS Environmental Corp., NUS Corp. and NUS Instruments. They are still in production. These devices include FCA, OCA and FIA versions with series designations 800 and 801. The only differences are the number of channels loaded, test jack size and LED power indicator colors. These devices all use modern switching power supplies in varying numbers dependent upon the output ranges and isolator types. FIA isolators have a separate power supply for each channel to give the outputs isolated commons. The circuit is operationally the same as earlier types and the actual isolation element is still the Burr-Brown 3656. These devices have undergone complete isolation type testing for dielectric withstand of 3000 Vdc and 1000 Vac, and most production units are tested to these values. The devices under went fault type testing to 480 Vac and 140 Vdc applied to all ports in the FIA800 series. Shorts, opens and inter-channel effects have also all been type tested. The devices have also been tested for surge withstand using the waveform specified in IEEE 472. All production units are 100% functionally tested prior to shipment. The chassis and electronics have been seismically proof tested for operation before, during and after the defined DBE with no anomalies. These devices use an aluminum chassis that is intended for rack mounting. The internals are accessible and passive air flow through the chassis removes internally generated heat. Outputs are fused on the rear and power is fused on the front of the devices. Span and zero adjustments are located on the front plate of the devices. These devices have the same life characteristics in the power supplies used but since they are not potted, the power supplies may be replaced allowing for the isolators to have 40 year life expectancies. All devices are manufactured using a 10CFR50 appendix B quality assurance program and are provided with 10CFR part 21 traceability as basic components.
- *** - J.E. Siedelmann, P.E. **** ***** **** Sr. Design Engineer ** ********* ** NUS Instruments, Inc. * *******
- Phone: (208) 524-9246
. *****. Fax: (208) 524-9238
** ***** ** jsiedelmann@scientech.com * 440 W. Broadway, Idaho Falls ' Idaho 83402-3638
RNP-I/INST-1070 Revision 16 ATTACHMENT H Document: __RNP_I/INST-1070__________________________________ Revision: __16___________ The signature of the Design Verification reviewer confirms: The type of verification method performed Technical errors have been resolved and the records have been included, if applicable _Yes__ Reviewer or ___ Concurrent Reviewer (Type "Yes" to indicate Reviewer type) Design Verification Review Method (Type "Yes" beside selection to indicate Review Method used) __Yes_ Design Review ___ Alternate Calculation ___ Qualification Testing (Type "Yes" to indicate if Records attached) Other Records: ___ Attached Note: This Record of Review form may be used to document other reviews, but is only required for Design Verification reviews. Reviewer (print/sign): Christy Ray (Electronically Approved) Discipline: Safety Analysis Models Date: (see Fusion) Item No. Technical Error Resolution None}}