View source for RNP-RA/17-0028, Submittal of Engineering Calculation in Support of a Request for Technical Specification Change to Change Technical Specification Surveillance Requirement Frequencies to Support 24-Month Fuel Cycles

{{Adams
| number = ML17093A796
| issue date = 04/03/2017
| title = Submittal of Engineering Calculation in Support of a Request for Technical Specification Change to Change Technical Specification Surveillance Requirement Frequencies to Support 24-Month Fuel Cycles
| author name = Kapopoulos E
| author affiliation = Duke Energy Progress, LLC
| addressee name = 
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000261
| license number = DPR-023
| contact person = 
| case reference number = RNP-RA/17-0028
| document type = Letter type:RNP
| page count = 124
| project = 
| stage = Request
}}

=Text=
{{#Wiki_filter:Ernest J. Kapopoulos, Jr.
(_~ DUKE                                                                        H. B. Robinson Steam Electric Plant Unit 2 ENERGY~                                                                       Site Vice President Duke Energy 3581 West Entrance Road Hartsville, SC 29550 0 : 843 857 1701 F: 843 857 1319 APR 0 3 Z017                                                             Emie.Kapopo11/os@JJ11ke-energy.co111 Serial: RNP-RA/17-0028 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 I RENEWED LICENSE NO. DPR-23 SUBMITTAL OF ENGINEERING CALCULATION IN SUPPORT OF A REQUEST FOR TECHNICAL SPECIFICATION CHANGE TO CHANGE TECHNICAL SPECIFICATION SURVEILLANCE REQUIREMENT FREQUENCIES TO SUPPORT 24-MONTH FUEL CYCLES

==Dear Sir/Madam:==

By letter dated September 16, 2016 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML16260A246), Duke Energy Progress, LLC (DEP) submitted a License Amendment Request to support a 24 month fuel cycle, but was withdrawn by letter dated November 10, 2016 (ADAMS Accession No. ML16315A242). The specific concerns that led to the withdrawal of the initial submittal were discussed by NRC letter dated November 21, 2016. These concerns have been addressed and a resubmittal of the License Amendment Request is being submitted under a separate cover.
The November 21, 2016 NRC letter also requested the submittal of a representative instrument calculation that was updated as a result of the License Amendment Request; the calculation, RNP-l/INST-1070, "Steam Generator Narrow Range Level Loop Uncertainty and Scaling Calculation," is provided as the Enclosure to this letter.

U.S. Nuclear Regulatory Commission Serial: RNP-RA/17-0028 Page 2 of 2 Please address any comments or questions regarding this matter to Mr. Tony Pila, Manager-Nuclear Regulatory Affairs at (843) 857-1409.
I declare under penalty of perjury that the foregoing is true and correct. Executed on c/'b {\f(l.I(..  , 2017.
Sincerely,
   ~
Ernest J. Kapopoulos, Jr.
Site Vice President EJK/jsk

==Enclosure:==

RNP-1/INST-1070, "Steam Generator Narrow Range Level Loop Uncertainty and Scaling Calculation" cc: Regional Administrator, NRG Region II Mr. Dennis J. Galvin NRG Project Manager, NRA NRG Resident Inspector, HBRSEP Ms. S. E. Jenkins, Manager, Infectious and Radioactive Waste Management Section (SC)
A. Gantt, Chief, Bureau of Radiological Health (SC)
Alan Wilson, Attorney General (SC)

U.S. Nuclear Regulatory Commission Enclosure to Serial: RNP-RA/17-0028 122 Pages (including cover page)
Calculation Number RNP-lnNST-1070 Steam Generator Narrow Range Level Loop Uncertainty and Scaling Calculation

Facility Code :            RNP Applicable Facilities :    RNP Document Number :          RNP-I/INST-1070 Document Revision Number : 011 Document EC Number :
Change Reason :            EC0000400739 Document Title :           STEAM GENERATOR NARROW RANGE LEVEL LOOP UNCERTAINTY AND SCALING CALCULATION Mungo, Jeffrey W            Preparer                          1/11/2017 Woodrum, Mark A             Approver                          1/19/2017 Notes :

Steam Generator Narrow Range Level Loop Uncertaintv and Scaling Calculation (LT-474, LT-475, LT-476. LT-484, l T-485. LT-486, LT-494, LT-495. LT-496)
Tiiie including structures, systems, and components RNP-l/JNST-1070                                                   11 Calculation Number                                               Rev#
System:  3005                                                     OSO List;    Yes  0  No [8l
[BNP, HNP, RNP) Sub-Type: IE                                           Microfiche Attachment List:   Yes  0  No 181 0 ualily Level: A                                                        Priority E:  Yes 0   No ~
D All D BNP Unit ----- D CNS Unit - - - - 0 HNP Unit 0 MNS Unit ----o                        D ONS Unit ---- ~ RNP Unit                          ----
2 0 General Office                            Keowee Hydro Station Originated By                      Design Veriftcalion Review By                    Approved By Verification Method Victor S. D'Amore Diie 1181 20 30 Other[)
DuWayne Wacha Kirk R. Melson I
J 2. 3o          JS 0  YES181 NO Check Box for Multiple Originators or Design Verifiers (see next page)
For Vendor Calculations:
Vendor:        Hurst Technologies, Corp.         Vendor Document #:               RNP-l/INST-1170 Ownel's Review By: ~~                                                           Date:
Approval By: ~~                                                          Date:

RNP-I/INST-1070 Revision 11 Page ii of ix LIST OF AFFECTED PAGES Calculation Number:                             RNP-I/INST-1070 Revision Number:                                       11 Body of Calculation (including appendices)                     Supporting Documents Rev. # Pages Revised Pages Deleted   Pages Added   Rev. #     Type    Pages Revised Pages Deleted   Pages Added 11                                      i-ix       11    Attachment                Att. A, 1-2 11       1-104                                     11    Attachment   Att. B, 1 11    Attachment   Att. C, 1 11    Attachment   Att. D, 1 11    Attachment                 Att. E, 1 11    Attachment                                Att. F, 1-2 11    Attachment                                Att. G, 1-2

RNP-I/INST-1070 Revision 11 Page iii of ix Calculation Number:                            RNP-I/INST-1070 Revision Number:                                        11 Revision Summary Revision   Summary 0        Initial issuance.
Revised calculation to consider seismic uncertainties. The format of the 1        calculation was revised to follow the calculation methodology presented in EGR-NGGC-0153.
Revised calculation to treat static pressure effects as dependent variables as 2
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&deg;F to 340&deg;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

RNP-I/INST-1070 Revision 11 Page iv of ix 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.
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&deg;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&deg;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.
Additional administrative changes: After receiving the vendor prepared revision it was identified calculation RNP-M/MECH-1651 is an additionally impacted document. This was documented on the CIRF for this calculation as part of EC 400739. This change is considered administrative and is being made while still maintaining the Quality Assurance records of the vendor and Owners Review record performed by RNP staff. Discussion of this document impact has been added to the discussion in Section 8. It has also been added to the Document Indexing Table.

RNP-I/INST-1070 Revision 11 Page v of ix Calculation Number:                               RNP-I/INST-1070 Revision Number:                                             11 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 E.G., CALC,        E.G., calculation number, IN for design inputs;      Calculation DWG,             equipment tag number,     OUT for affected       E.G., design input, PROCEDURE,             procedure number,                              assumption basis, TAG,           software name and version                         reference, document SOFTWARE                                                             affected by results CALC              INST-I/INST-1212                  IN                Reference CALC              INST-I/INST-1215                  IN                Reference PROC                    MST-013                     IN                Reference PROC                    PIC-005-1                   IN                Reference PROC                    PIC-005-2                   IN                Reference PROC                    PIC-005-4                   IN                Reference PROC                    PIC-005-6                   IN                Reference PROC                    PIC-005-8                   IN                Reference PROC                    PIC-005-9                   IN                Reference PROC                   PIC-005-10                   IN                Reference PROC                 EOP-ECA-0.0                    IN                Reference PCHG                    EC 97661                    IN                Reference CALC                                                                  Document RNP-M/MECH-1651                   OUT affected by results

RNP-I/INST-1070 Revision 11 Page vi of ix Table of Contents SEC     DESCRIPTION                                                                                                                 PAGE 1.0 OBJECTIVE ..............................................................................................................................1 2.0 FUNCTIONAL DESCRIPTION ...............................................................................................2 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) ....................................................................21 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 (RA xmtr ) .....................46 6.6.2 Transmitter Calibration Tolerance (CAL xmtr ) ...........................................................46 6.6.3 Transmitter Drift (DR xmtr ) ........................................................................................47 6.6.4 Transmitter M&TE Effect (MTE xmtr ) .......................................................................47 6.6.5 Transmitter Temperature Effect (TE xmtr ) ..................................................................48 6.6.6 Normal Transmitter Static Pressure Effect (norSPE xmtr ) ..........................................49 6.6.7 Accident Transmitter Static Pressure Effect (accSPE xmtr ) ........................................50 6.6.8 Transmitter Power Supply Effect (PSE xmtr )..............................................................50 6.6.9 Normal Transmitter Total Device Uncertainty (norTDU xmtr ) ..................................51 6.6.10 Normal Transmitter Total Device Uncertainty (eopTDU xmtr ) for EOPs ................51 6.6.11 Accident Transmitter Total Device Uncertainty (accTDU xmtr ) ..............................51 6.6.12 Transmitter As Found Tolerance (AFT xmtr )............................................................52 6.6.13 Transmitter As Left Tolerance (AL T xmtr ) ..............................................................53

RNP-I/INST-1070 Revision 11 Page vii of ix 6.7 COMPARATOR MODULE ...........................................................................................54 6.7.1 Comparators Unverified Attributes of Reference Accuracy (RA comp ) ....................54 6.7.2 Comparator Calibration Tolerance (CAL comp ) .........................................................54 6.7.3 Comparator Drift (DR comp ) .......................................................................................54 6.7.4 Comparator M&TE Effect (MTE comp )......................................................................55 6.7.5 Comparator Temperature Effect (TE comp ) ................................................................55 6.7.6 Comparator Power Supply Effect (PSE comp ) ............................................................55 6.7.7 Comparator Total Device Uncertainty (TDU comp )....................................................55 6.7.8 Comparator As Found Tolerance (AFT comp ) ............................................................56 6.7.9 Comparator As Left Tolerance (ALT comp )................................................................56 6.8 ISOLATOR MODULE ...................................................................................................57 6.8.1 Isolators Unverified Attributes of Reference Accuracy (RA isol ) .............................57 6.8.2 Isolator Calibration Tolerance (CAL isol ) ..................................................................57 6.8.3 Isolator Drift (DR isol ) ................................................................................................57 6.8.5 Isolator Temperature Effect (TE isol ) .........................................................................59 6.8.6 Isolator Power Supply Effect (PSE isol ) .....................................................................60 6.8.7 Isolator Total Device Uncertainty (TDU isol ).............................................................60 6.8.8 Isolator As Found Tolerance (AFT isol ) .....................................................................61 6.8.9 Isolator As Left Tolerance (ALT isol ).........................................................................62 6.9 INDICATOR......................................................................................................................63 6.9.1 Indicators Unverified Attributes of Reference Accuracy (RA ind ) ...........................63 6.9.2 Indicator Calibration Tolerance (CAL ind ).................................................................63 6.9.3 Indicator Drift (DR ind ) ..............................................................................................63 6.9.5 Indicator Temperature Effect (TE ind )........................................................................64 6.9.6 Indicator Power Supply Effect (PSE ind ) ...................................................................64 6.9.7 Indicator Readability (RD ind )....................................................................................64 6.9.8 Indicator Total Device Uncertainty (TDU ind ) ...........................................................65 6.9.9 Indicator Total Device Uncertainty for EOP Setpoints (eopTDU ind ) .......................65 6.9.10 Indicator As Found Tolerance (AFT ind ) .................................................................66 6.9.11 Indicator As Left Tolerance (ALT ind ) .....................................................................67 6.10 RECORDER ....................................................................................................................68 6.10.1 Recorders Unverified Attributes of Reference Accuracy (RA rec ) .........................68 6.10.2 Recorder Calibration Tolerance (CAL rec )...............................................................68 6.10.3 Recorder Drift (DR rec ) ............................................................................................69 6.10.4 Recorder M&TE Effect (MTE rec ) ...........................................................................69 6.10.5 Recorder Temperature Effect (TE rec ) .....................................................................69 6.10.6 Recorder Power Supply Effect (PSE rec ) .................................................................69 6.10.7 Recorder Readability (RD rec )..................................................................................70 6.10.8 Recorder Total Device Uncertainty (TDU rec ) .........................................................70 6.10.9 Recorder As-Found Tolerance (AFT rec ) ................................................................70 6.10.10 Recorder As Left Tolerance (ALT rec ) ..................................................................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

RNP-I/INST-1070 Revision 11 Page viii of ix 7.1.6 Total Loop Uncertainty - Low Level Alarm .............................................................75 7.1.7 Total Loop Uncertainty - Input to AMSAC ..............................................................76 7.2 TOTAL LOOP UNCERTAINTY - ACCIDENT ...........................................................78 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 ...............................................................94 8.2 Impact On Ufsar ..............................................................................................................94 8.3 Impact On Design Basis Documents ...............................................................................94 8.4 Impact On Other Calculations .........................................................................................94 8.5 Impact On Plant Procedures ............................................................................................95 9.0 SCALING CALCULATIONS.................................................................................................96 9.1 Level Transmitter (LT-474, 475, 476, 484, 485, 486, 494, 495, And 496) .......................96 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) .........................99 9.3 Comparator Module (LC-474, 475, 476, 484, 485, 486, 494, 495, & 496) .....................100 9.4 Comparator Module (LC-474A, 475A, 476A, 484A, 485A, 486A, 494A, 495A, &
496A) ...............................................................................................................................101 9.5 Comparator Module (LC-474B, 475B, 484B, 485B, 494B, & 495B) .............................102 9.6 Indicator (LI-474, 475, 476, 484, 485, 486, 494, 495, & 496) ........................................103 9.7 Recorder (FR-478, 488, & 498) .......................................................................................104

RNP-I/INST-1070 Revision 11 Page ix of ix 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

RNP-I/INST-1070 Revision 11 Page 1 of 104 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 instrument loops containing the following components are addressed in this calculation:
LT-474                        LT-484                        LT-494 LQ-474                        LQ-484                        LQ-494 L-474                         L-484                         L-494 LC-474                        LC-484                        LC-494 LC-474A                       LC-484A                       LC-494A LM-474                        LM-484                        LM-494 LC-474B                       LC-484B                       LC-494B LI-474                        LI-484                        LI-494 LM-474A                       LM-484A                       LM-494A LM-474B                       LM-484/R                      LM-494/R LM-474/R                      LC-484/R                      LC-494/R LC-474/R                      LC-484A/R                     LC-494A/R LC-474A/R LT-475                        LT-485                        LT-495 LQ-475                        LQ-485                        LQ-495 L-475                         L-485                         L-495 LC-475                        LC-485                        LC-495 LC-475A                       LC-485A                       LC-495A LM-475                        LM-485                        LM-495 LC-475B                       LC-485B                       LC-495B LI-475                        LI-485                        LI-495 LM-475A                       LM-485A                       LM-495A LM-475A/R                     LM-485B                       LM-495/R LC-475/R                      LM-485A/R                     LC-495/R LC-475A/R                     LC-485/R                      LC-495A/R LC-485A/R LT-476                        LT-486                        LT-496

RNP-I/INST-1070 Revision 11 Page 2 of 104 LQ-476                           LQ-486                        LQ-496 L-476                            L-486                         L-496 LC-476                           LC-486                        LC-496 LC-476A                          LC-486A                       LC-496A LM-476                           LM-486                        LM-496 LI-476                           LI-486                        LI-496 FR-478                           FR-488                        FR-498 LM-476A                          LM-486A                       LM-496A LM-476/R                         LM-486A/R                     LM-496B LC-476/R                         LC-486/R                      LM-496A/R LC-476A/R                        LC-486A/R                     LC-496/R LC-496A/R 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

RNP-I/INST-1070 Revision 11 Page 3 of 104 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 11 Page 4 of 104 3.0 LOOP DIAGRAM Note: Same configuration for loops L-475, 476, 484, 485, 486, 494, 495, and 496 except where noted.

RNP-I/INST-1070 Revision 11 Page 5 of 104 TAG NUMBER      FUNCTION    MAKE AND MODEL    LOCATION          REFERENCE LT- 474, 475, 476 Transmitter Rosemount 1154DP4 Containment 4.1.1-8, 4.7.4 LT- 484, 485, 486 LT- 494, 495, 496 LQ- 474, 475, 476 Power       NUS SPS 800       Hagan Rack  4.1.1-8, 4.7.4 LQ- 484, 485, 486 Supply LQ- 494, 495, 496 LM-474/R,         I/V         Hagan Model       Hagan Rack  4.1.1-8, 4.7.4 LC-474/R, 474A/R              3110554-000 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 LM-474A, 475A     I/I         NUS EIP-E013DD-1  Hagan Rack  4.1.1-8, 4.7.4 LM-476A, 484A     Isolator LM-485A, 486A LM-494A, 495A LM-496A

RNP-I/INST-1070 Revision 11 Page 6 of 104 TAG NUMBER     FUNCTION    MAKE AND MODEL         LOCATION          REFERENCE LM-474, 475, 476  V/I        NUS OCA 800             Hagan Rack 4.1.1-8, 4.7.4 LM-484, 485, 486  Isolator LM-494, 495, 496 LM-474B, 485B     V/I        NUS EIP-E013DD-37       Hagan Rack 4.1.1-8, 4.7.4 LM-496B           Isolator LC-474, 475, 476  Comparator Hagan Model 139-118     Hagan Rack 4.1.1-8, 4.7.4 LC-484, 485, 486             Or NUS SAM 800 LC-494, 495, 496             Or NUS DAM 800 LC-474A, 475A LC-476A, 484A LC-485A, 486A LC-494A, 495A LC-496A, 474B LC-475B, 484B LC-485B, 494B LC-495B LI- 474, 475, 476 Indicator  International           RTGB       4.1.1-8, 4.7.4 LI- 484, 485, 486            Instruments 2520VB LI- 494, 495, 496 FR-478, 488, 498  Recorder   Yokogawa VR204          RTGB       4.7.4, 4.7.15 L-474, 475, 476   I/V        Hagan Computer          Hagan Rack 4.1.1-8, 4.7.4 L-484, 485, 486              Signal Conditioner L-494, 495, 496              3110552-000 Instrument Identification

RNP-I/INST-1070 Revision 11 Page 7 of 104

==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 4.3 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 11 Page 8 of 104 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 37 4.4.4 728-208-63. VERTICAL STEAM GENERATOR TECHNICAL MANUAL, Revision 22 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 11 Page 9 of 104 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 4.7 Other References 4.7.1  Updated Final Safety Analysis Report - Chapter 15, Revision 25.
4.7.2  Technical Specifications, Amendment 236 (For information only) 4.7.3  RNP-F/NFSA-0230, RNP Cycle 30 Plant Parameters Document, Revision 1 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 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

RNP-I/INST-1070 Revision 11 Page 10 of 104 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)

RNP-I/INST-1070 Revision 11 Page 11 of 104 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 4.6.1.
5.2 Per Reference 4.7.11 (a) and (b), the maximum Containment temperature following an accident is 280&deg;F. Per Reference 4.7.16, the maximum Containment temperature by analysis following an accident is 340&deg;F, which occurs within the first 60 seconds of the transient. The temperature then quickly falls below 280&deg;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&deg;F. Per Reference 4.1.9, the minimum Containment temperature during normal operation is 88&deg;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&deg;F and 88&deg;F respectively for non-EOP applications and 280&deg;F and 88&deg;F respectively for EOP applications. In the event of a single feedwater line break, per WCAP-16115P, the maximum containment temperature is 225&deg;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&deg;F is used in the Containment analysis. For conservatism, the temperature inside the shield wall is assumed to be 140&deg;F and is used to compute normal reference leg density effects. Per Reference 4.1.9, the minimum temperature inside Containment is 88&deg;F. Therefore, a minimum temperature of 88&deg;F is used to compute normal reference leg density effects.
5.5 Per Reference 4.6.1, 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 11 Page 12 of 104 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 4.6.1.
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 130&#xba;F. Technical Specification 3.6.5 limits containment average air temperature to less than or equal to 120&#xba;F. For the purpose of this calculation, 130&#xba;F 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 60&#xba;F. For the purpose of this calculation, 50&#xba;F will be used as the lower limit for containment temperature.
5.8 The Hagan Room normal operating temperature is 50&deg;F to 82&#xba;F. The low limit of 50&#xba;F is chosen as it is the more conservative value when comparing the 50&#xba;F alarm setpoint
[from Reference 4.6.3] for TS-A42 (HVA-2 Lo Temp Switch) and the 55&#xba;F heater setpoint [from Reference 4.6.4] for TS-A40 (Temperature Switch for EDH-4). The basis for the 82&#xba;F is the Hot Operations Log (TIN R0041). The hot operations log directs the installation of supplemental cooling when Hagan Room temperatures reach 78&#xba;F, and the initiation of an NCR and an operability review when Hagan Room temperatures reach 82&#xba;F. Per Reference 4.6.1 Section 9.4.3, the racks may experience an additional internal 10&deg;F heat rise during operation. Therefore, a change in temperature of 42&deg;F (23.33&deg;C) is used to compute the normal temperature effect associated with rack components in setpoint and normal indication loops.
82&deg;F + 10&deg;F  50&deg;F = 42&deg;F The Hagan Room accident operating temperature is 50&#xba;F to 120&#xba;F. 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 110&#xba;F when the SPP-045 controls are applied. For conservatism, the high limit is taken to be 120&#xba;F. 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&deg;F (38.89&deg;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 resistor. Based on the high accuracy of the resistor, the resistor has a negligible impact

RNP-I/INST-1070 Revision 11 Page 13 of 104 on the overall loop uncertainty computation.
5.10    Per Reference 4.7.3, the lowest set pressure of the Steam Generator safety relief 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.
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. Per Reference 4.7.3, no analytical limit is specified for this setpoint. 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 Thus, MD as a % of Narrow Range Span is:

RNP-I/INST-1070 Revision 11 Page 14 of 104 114.4425 MD =                 = 79.751% of Span 143.5 Therefore:
MRIL = 100%  (100%  MD) (11%)
MRIL = 97.773 % Level This MRIL value is conservatively rounded to 97.77% Narrow Range Level and will, as suggested in NSAL-02-4, be used as the analytical limit for the High Level Valve Interlock addressed in this calculation.
5.14 Per Reference 4.7.20, the Control Room normal operating temperature is 70&#xba;F to 77&#xba;F dry bulb, inclusive under all modes of operation. Per Reference 4.7.21, the normal ambient design temperature for Control Room located equipment is 75&#xba;F (plus or minus 10&#xba;F), which can also be stated as a temperature range of 65 &#xba;F to 85 &#xba;F. Per Reference 4.7.2, the Control Room Emergency Air Temperature Control (CREATC) maintains the Control Room temperature less than or equal to 85&#xba;F. Therefore, a maximum change in temperature of 20&#xba;F (11.1&#xba;C) 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).
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 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

RNP-I/INST-1070 Revision 11 Page 15 of 104 using the specific gravity of water, 0.0160454 ft3 / lbm, and the transmitter calibrated span of 108 inches (Section 6.4.1) as follows:
0.19 pounds   0.0160454 ft 3
144 in 2    12 in MDDPb =                                                       = 5.27 inches in 2         pound           ft 2
ft 100% Span MDDPb = 5.27 inches                   = 4.88% Span 108 inches For normal (non transient operational conditions, the Mid Deck Plate pressure drop remains as follows:
0.17 pounds   0.0160454 ft        144 in 2     12 in 3
MDDPb =
in 2 pound           ft 2        ft  = 4.71 inches 100% Span MDDPb = 4.71 inches                  = 4.36% Span 108 inches 5.19 Technical information included in Reference 4.7.15 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 4.7.15.
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 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

RNP-I/INST-1070 Revision 11 Page 16 of 104 to inches of H 2 O (at 500&deg;F, 900 psia) as follows:
1 inch water = 49.03889 lb/ft3 X (1/12 ft/in)3 X 1 in H 2 O = .02838 psi 1"WATER (0.006 PSI ) = 0.211INCHES_WATER 0.02838 PSI SPAN = 108 INCHES 0.211 FEED RING %SPAN =                 100 = 0.195 % Span 108 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%.
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&deg;F. This impacts the normal

RNP-I/INST-1070 Revision 11 Page 17 of 104 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 @ 68&#xba;F / 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 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

RNP-I/INST-1070 Revision 11 Page 18 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), 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 11 Page 19 of 104 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 1154DP4. Per Reference 4.4.3, the transmitter Accident Temperature Effect (ATE xmtr ) is given as +/- 2.5% Upper Range Limit plus 0.50% Span. The Upper Range Limit (URL) of a range code 4 transmitter is 150 inwc. Per Section 9.1, the span of each transmitter is 108 inwc. Therefore, the ATE xmtr associated with each transmitter is computed as follows:

RNP-I/INST-1070 Revision 11 Page 20 of 104 150 inwc ATE xmtr = +/- { (2.50% )            + 0.50% Span }
108 inwc ATE xmtr = +/- 3.97% 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 1154DP4. Per Reference 4.4.3, the transmitter Accident Radiation Effect (ARE xmtr ) is given as +/- 1.5% Upper Range Limit plus 1.00% Span. The Upper Range limit (URL) of a range code 4 transmitter is 150 inwc. Per Section 9.1, the span of each transmitter is 108 inwc. Therefore, the ARE xmtr associated with each transmitter is computed as follows:
150 inwc ARE xmtr = +/-{  (1.50% )            + 1.00% Span }
108 inwc ARE xmtr = +/- 3.08% Span 6.2 SEISMIC EFFECT (SE)
Per EDB, the transmitter in each loop is a Rosemount 1154DP4. 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 4 transmitter is 150 inwc. Per Section 9.1 of this calculation, the calibrated span of each loop is 108 inwc. Therefore, 150 inwc SE xmtr = +/- 0.50% URL                = +/- 0.69% Span 108 inwc 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.

RNP-I/INST-1070 Revision 11 Page 21 of 104 6.3 INSULATION RESISTANCE ERROR (IR)
Per RNP-I/EQ-1175, the Insulation Resistance (IR) effect associated with the loop signal cabling inside Containment is a worst case bias of +2.1896% Span for LT-474. Therefore, IR = +2.19% 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) = h SG WN + (H  h ) SG SN  H SG RN  PC
: where, h =    height of fluid (inches)
H =    height of measured level span = 143.5 inches (Section 9.1)
SG WN  = specific gravity of fluid during operation SG SN  = specific gravity of steam during operation SG RN  = specific gravity of reference leg fill fluid during operation P C   = differential pressure associated with a particular level measurement at conditions assumed for scaling.
P Span = 108 inwc (Section 9.1)
Therefore, PME (inwc)
PME(% Span) =                 100% Span P Span Per Section 9.1, the following conditions are assumed for loop scaling:
SG WC = 0.787341 @ 900 psia, 500&deg;F SG SC = 0.032034 @ 900 psia, saturated SG RC = 0.992946 @ 900 psia, 120&deg;F, compressed

RNP-I/INST-1070 Revision 11 Page 22 of 104 The differential pressure associated with a particular level measurement is computed with the following equation:
P C = h SGWC + (H  h ) SGSC  H SG RC Differential pressures are computed for the specific points of interest across the level span:
Fluid       Fluid Calibrated Height      Height          PC
(% Span)        (in)        (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 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&deg;F to 140&deg;F (Reference leg temperature)
A total of four possible conditions are considered for normal operation:
Case I       Reference Leg = 88&deg;F, 1020 psia Process Pressure = 1020 psia, saturated Case II      Reference Leg = 140&deg;F, 1020 psia Process Pressure = 1020 psia, saturated Case III     Reference Leg = 88&deg;F, 800 psia Process Pressure = 800 psia, saturated Case IV      Reference Leg = 140&deg;F, 800 psia Process Pressure = 800 psia, saturated

RNP-I/INST-1070 Revision 11 Page 23 of 104 Case I SG RN = 1.000125 @ 88&deg;F, 1020 psia SG SN = 0.036786 @ 1020 psia saturated SG WN = 0.740813 @ 1020 psia saturated The following equations are used to compute the values in the table below:
Actual PN (inwc ) = h SG WN + (H - h ) SG SN - H SG RN norPME(inwc ) = Actual PN (inwc )  Calibrated PC (inwc )
norPME (inwc )
norPME (% Span ) =                  100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid       Fluid      Actual       Calibrated Height    Height         PN             PC      norPME      norPME
(% Span)       (in)      (inwc)          (inwc)      (inwc)    (% 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 11 Page 24 of 104 Case II SG RN = 0.988054 @ 140&deg;F, 1020 psia SG SN = 0.036786 @ 1020 psia saturated SG WN = 0.740813 @ 1020 psia saturated The following equations are used to compute the values in the table below:
Actual PN (inwc ) = h SG WN + (H - h ) SG SN - H SG RN norPME(inwc ) = Actual PN (inwc )  Calibrated PC (inwc )
norPME (inwc )
norPME (% Span ) =                  100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid       Fluid      Actual       Calibrated Height     Height        PN            PC        norPME     norPME
(% Span)        (in)      (inwc)         (inwc)        (inwc)   (% 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 11 Page 25 of 104 Case III SG RN = 0.999502 @ 88&deg;F, 800 psia SG SN = 0.028202 @ 800 psia saturated SG WN = 0.768855 @ 800 psia saturated The following equations are used to compute the values in the table below:
Actual PN (inwc ) = h SG WN + (H - h ) SG SN - H SG RN norPME(inwc ) = Actual PN (inwc )  Calibrated PC (inwc )
norPME (inwc )
norPME (% Span ) =                  100% Span P Span where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid        Fluid      Actual       Calibrated Height     Height         PN             PC      norPME     norPME
(% Span)        (in)      (inwc)          (inwc)      (inwc)   (% 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 11 Page 26 of 104 Case IV SG RN = 0.987446 @ 140&deg;F, 800 psia SG SN = 0.028202 @ 800 psia saturated SG WN = 0.768855 @ 800 psia saturated The following equations are used to compute the values in the table below:
Actual PN (inwc ) = h SG WN + (H - h ) SG SN - H SG RN norPME(inwc ) = Actual PN (inwc )  Calibrated PC (inwc )
norPME (inwc )
norPME (% Span ) =                  100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid       Fluid      Actual       Calibrated Height    Height         PN             PC      norPME      norPME
(% Span)       (in)      (inwc)          (inwc)      (inwc)    (% 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 11 Page 27 of 104 The following table presents the maximum positive and negative process measurement effects computed above for Cases I through IV.
Fluid       Fluid      Positive     Negative Height      Height      norPME       norPME
(% Span)        (in)     (% Span)     (% 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%
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 setpoints.

RNP-I/INST-1070 Revision 11 Page 28 of 104 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 U CARRYUNDER = 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        Fluid        Positive     Negative Height       Height        norPME       norPME
(% Span)         (in)       (% Span)     (% 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 11 Page 29 of 104 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) = h SG WN + (H  h ) SG SN  H SG RN  PC where, h = height of fluid (inches)
H = height of measured level span = 143.5 inches (Section 9.1)
SG WN = specific gravity of fluid during operation SG SN = specific gravity of steam during operation SG RN = specific gravity of reference leg fill fluid during operation P C = differential pressure associated with a particular level measurement at conditions assumed for scaling.
P Span = 108 inwc (Section 9.1)
Therefore, PME (inwc)
PME(% Span) =                 100% Span P Span Per Section 9.1, the following conditions are assumed for loop scaling:
SG WC = 0.787341 @ 900 psia, 500&deg;F SG SC = 0.032034 @ 900 psia, saturated SG RC = 0.992946 @ 900 psia, 120&deg;F, compressed

RNP-I/INST-1070 Revision 11 Page 30 of 104 The differential pressure associated with a particular level measurement is computed with the following equation:
P C = h SG WC + (H - h ) SG SC - H SG RC Differential pressures are computed for the specific points of interest across the level span:
Fluid        Fluid Calibrated Height        Height           PC
(% Span)          (in)         (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 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&deg;F to 340&deg;F (Reference leg temperature)
A total of four possible conditions are considered for accident operation:
Reference Leg = 88&deg;F, 15 psia Case I Process Pressure = 15 psia, saturated Reference Leg = 15 psia, saturated Case II Process Pressure = 15 psia, saturated Reference Leg = 88&deg;F, 1100 psia Case III Process Pressure = 1100 psia, saturated Reference Leg = 340&deg;F, 1100 psia Case IV Process Pressure = 1100 psia, saturated

RNP-I/INST-1070 Revision 11 Page 31 of 104 Case I SG RA = 0.997018 @ 88&deg;F, 15 psia SG SA = 0.000610 @ 15 psia saturated SG WA = 0.959345 @ 15 psia saturated The following equations are used to compute the values in the table below:
Actual PA (inwc ) = h SG WA + (H - h ) SG SA - H SG RA accPME(inwc ) = Actual PA (inwc )  Calibrated PC (inwc )
accPME(inwc )
accPME(% Span ) =                  100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid         Fluid     Actual       Calibrated Height      Height        PA             PC      accPME      accPME
(% Span)         (in)     (inwc)          (inwc)      (inwc)    (% 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 11 Page 32 of 104 Case II SG RA = 0.959345 @ 15 psia, saturated SG SA = 0.000610 @ 15 psia saturated SG WA = 0.959345 @ 15 psia saturated The following equations are used to compute the values in the table below:
Actual PA (inwc ) = h SG WA + (H - h ) SG SA - H SG RA accPME(inwc ) = Actual PA (inwc )  Calibrated PC (inwc )
accPME(inwc )
accPME(% Span ) =                  100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid       Fluid      Actual       Calibrated Height      Height        PA             PC     accPME       accPME
(% Span)         (in)     (inwc)          (inwc)       (inwc)   (% 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 11 Page 33 of 104 Case III SG RA = 1.000125 @ 88&deg;F, 1100 psia SG SA = 0.040057 @ 1100 psia saturated SG WA = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below:
Actual PA (inwc ) = h SG WA + (H - h ) SG SA - H SG RA accPME(inwc ) = Actual PA (inwc )  Calibrated PC (inwc )
accPME(inwc )
accPME(% Span ) =                  100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid       Fluid      Actual       Calibrated Height      Height        PA             PC     accPME       accPME
(% Span)         (in)     (inwc)          (inwc)       (inwc)   (% 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 11 Page 34 of 104 Case IV SG RA = 0.901967 @ 340&deg;F, 1100 psia SG SA = 0.040057 @ 1100 psia saturated SG WA = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below:
Actual PA (inwc ) = h SG WA + (H - h ) SG SA - H SG RA accPME(inwc ) = Actual PA (inwc )  Calibrated PC (inwc )
accPME(inwc )
accPME(% Span ) =                   100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid Height     Fluid Height       Actual          Calibrated    accPME         accPME
(% span)           h (in)      P A (inwc)       P C (inwc)     (inwc)        (% 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 11 Page 35 of 104 The following table presents the maximum positive and negative process measurement effects computed above for Cases I through IV.
Positive                        Negative Fluid Height     Fluid Height accPME           CASE #           accPME          CASE #
(% span)           h (in)
(% span)                         (% span) 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&deg;F. Using the above methodology and the following values:
SG RA = 0.958283 @ 225&deg;F, 1020 psia SG SA = 0.036795 @ 1020 psia saturated SG WA = 0.740776 @ 1020 psia saturated Then, the accPME at 0% level (condition of interest) is:
Fluid Fluid     Actual       Calibrated Height                                              accPME        accPME Height       Pa            Pc
(%                                                 (inwc)      (% Span)
(in)     (inwc)         (inwc)
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 11 Page 36 of 104 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%.
Positive      Negative Fluid Height    Fluid Height accPME         accPME
(% span)           h (in)
(% span)       (% 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          Fluid     Positive    Negative Height        Height     accPME      accPME
(% Span)         (in)    (% Span)    (% Span) 0.00%           0.00      5.79%      -11.72%

RNP-I/INST-1070 Revision 11 Page 37 of 104 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&deg;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) = h SG WN + (H  h ) SG SN  H SG RN  PC where, h =     height of fluid (inches)
H =     height of measured level span = 143.5 inches (Section 9.1)
SG WN   = specific gravity of fluid during operation SG SN   = specific gravity of steam during operation SG RN   = specific gravity of reference leg fill fluid during operation P C    = differential pressure associated with a particular level measurement at conditions assumed for scaling.
P Span = 108 inwc (Section 9.1)
Therefore, PME (inwc)
PME(% Span) =                  100% Span P Span 

RNP-I/INST-1070 Revision 11 Page 38 of 104 Per Section 9.1, the following conditions are assumed for loop scaling:
SG WC = 0.787341 @ 900 psia, 500&deg;F SG SC = 0.032034 @ 900 psia, saturated SG RC = 0.992946 @ 900 psia, 120&deg;F, compressed The differential pressure associated with a particular level measurement is computed with the following equation:
P C = h SG WC + (H  h ) SG SC  H SG RC Differential pressures are computed for the specific points of interest across the level span:
Fluid      Fluid Calibrated Height     Height         PC
(% Span)       (in)       (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 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&deg;F to 190&deg;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.

RNP-I/INST-1070 Revision 11 Page 39 of 104 Case Ie   Reference Leg = 88&deg;F, 1100 psia Process Pressure = 1100 psia, saturated Case IIe  Reference Leg = 190&deg;F, 1100 psia Process Pressure = 1100 psia, saturated Case IIIe Reference Leg = 88&deg;F, 15 psia Process Pressure = 15 psia, saturated Case IVe  Reference Leg = 190&deg;F, 15 psia Process Pressure = 15 psia, saturated Case Ie SG RA = 1.000125 @ 88&deg;F, 1100 psia SG SA = 0.040057 @ 1100 psia saturated SG WA = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below:
Actual PN (inwc ) = h SG WN + (H - h ) SG SN - H SG RN norPME(inwc ) = Actual PN (inwc )  Calibrated PC (inwc )
norPME (inwc )
norPME (% Span ) =                   100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Calculated    Calculated Fluid Height     Fluid Height     Actual dP       Calibrated dP eopPME        eopPME
(% span)            (in)           (inwc)            (inwc)
(inwc)       (% 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 11 Page 40 of 104 Case IIe SG RN = 0.971896 @ 190&deg;F, 1100 psia SG SN = 0.040057 @ 1100 psia saturated SG WN = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below:
Actual PN (inwc ) = h SG WN + (H  h ) SG SN  H SG RN norPME(inwc ) = Actual PN (inwc )  Calibrated PC (inwc )
norPME (inwc )
norPME (% Span ) =                   100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Calculated     Calculated Fluid Height     Fluid Height     Actual dP       Calibrated dP eopPME         eopPME
(% span)            (in)           (inwc)           (inwc)
(inwc)        (% 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 11 Page 41 of 104 Case IIIe SG RA = 0.997018 @ 88&deg;F, 15 psia SG SA = 0.000610 @ 15 psia saturated SG WA = 0.959345 @ 15 psia saturated The following equations are used to compute the values in the table below:
Actual PA (inwc ) = h SG WA + (H  h ) SG SA  H SG RA accPME(inwc ) = Actual PA (inwc )  Calibrated PC (inwc )
accPME(inwc )
accPME(% Span ) =                   100% Span P Span where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Calculated     Calculated Fluid Height      Fluid Height     Actual dP       Calibrated dP eopPME         eopPME
(% span)            (in)          (inwc)           (inwc)
(inwc)        (% 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 11 Page 42 of 104 Case IVe SG RN = 0.968377 @ 190&deg;F, 15 psia SG SN = 0.000610 @ 15 psia saturated SG WN = 0.959345 @ 15 psia saturated The following equations are used to compute the values in the table below:
Actual PN (inwc ) = h SG WN + (H  h ) SG SN  H SG RN norPME(inwc ) = Actual PN (inwc )  Calibrated PC (inwc )
norPME (inwc )
norPME (% Span ) =                  100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Calculated     Calculated Fluid Height     Fluid Height     Actual dP       Calibrated dP eopPME         eopPME
(% span)            (in)           (inwc)           (inwc)
(inwc)        (% 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 11 Page 43 of 104 The following table presents the maximum positive and negative process measurement effects computed above for Cases I through IV.
Positive      Negative Fluid Height     Fluid Height eopPME         eopPME
(% span)            (in)
(% span)       (% 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 11 Page 44 of 104 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&deg;F and 88&deg;F respectively. For EOP applications the maximum and minimum Containment temperatures should be 280&deg;F and 88&deg;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 SG RA = 0.933450 @ 280&deg;F, 1100 psia SG SA = 0.040057 @ 1100 psia saturated SG WA = 0.731025 @ 1100 psia saturated The following equations are used to compute the values in the table below:
Actual PA (inwc ) = h SG WA + (H  h ) SG SA  H SG RA accPME(inwc ) = Actual PA (inwc )  Calibrated PC (inwc )
acceopPME(inwc )
acceopPME(% Span ) =                        100% Span P Span
: where, P Span = 108 inwc (Section 9.1)
Calibrated P C is computed above.
H = 143.5 inches (Section 9.1)
Fluid Height     Fluid Height        Actual          Calibrated acceopPME      acceopPME
(% span)           h (in)       P A (inwc)       P C (inwc)    (inwc)        (% 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 11 Page 45 of 104 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.
Positive                        Negative Fluid Height     Fluid Height acceopPME                        acceopPME
(% span)            h (in)                        CASE #                        CASE #
(% span)                         (% span) 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%.
Positive      Negative Fluid Height   Fluid Height acceopPME       acceopPME
(% span)         h (in)
(% span)       (% 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 11 Page 46 of 104 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 +/- 0.25% 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is utilized to compute the repeatability portion of the transmitter reference accuracy:
RA xmtr      0.25% Span Repeatability = +/-           =+/-                = +/- 0.14% Span 3              3 Therefore, RA xmtr = +/- 0.14% 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

RNP-I/INST-1070 Revision 11 Page 47 of 104 6.6.3 Transmitter Drift (DRxmtr)
Per Attachment C, the transmitter drift is given as +/- 0.20% Upper Range Limit (URL) over a time period of thirty months. Per Reference 4.4.3, the URL for a range code 4 transmitter is 150 inwc. Per Section 9.1, the calibrated span of the transmitter is 108 inwc. Therefore, 0.20% URL               150 inwc DR xmtr = +/-               = +/-0.20%             = +/- 0.28% Span Span                 108 inwc 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, AD xmtr         = +/- 1.044% Span AD xmtrBIAS =  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 EGR-NGGC-0153 (Reference 4.6.1), 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.
MTE xmtr = +/- 0.50% Span

RNP-I/INST-1070 Revision 11 Page 48 of 104 6.6.5 Transmitter Temperature Effect (TExmtr)
Per Reference 4.4.3, the transmitter temperature effect is given as +/- 0.75% Upper Range Limit + 0.50% Span for a change in temperature of 100&deg;F from the temperature at which the transmitter was calibrated. Per Reference 4.4.3, the Upper Range Limit (URL) for a range code 4 transmitter is 150 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&deg;F and 130&deg;F respectively (Design Input 5.7). Therefore, a maximum change in temperature of 80&deg;F is used to calculate the transmitter temperature effect. Therefore, 0.75% URL                      T TE xmtr = +/-                + 0.50% Span Span                       100&deg;F 150 inwc                   80&deg;F TE xmtr = +/-  0.75%              + 0.50% Span           = +/- 1.23% Span 108 inwc                   100&deg;F Per Design Input 5.22, the maximum containment temperature when using normal containment setpoint values is 190&deg;F. As discussed above, the minimum containment temperature is 50&deg;F. Therefore, a maximum change in temperature of 140&deg;F is used to calculate the transmitter temperature effect. Therefore, 0.75% URL                      T eopTE xmtr = +/-                 + 0.50% Span Span                       100&deg;F 150 inWC                     140&deg; F eopTE xmtr = +/-  0.75%                + 0.50% Span            = +/-2.16% Span 108 inWC                     100&deg; F 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 11 Page 49 of 104 6.6.6 Normal Transmitter Static Pressure Effect (norSPExmtr)
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 +/- 0.50% Reading 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 +/- 0.20% Upper Range Limit per 1000 psi, and the Upper Range Limit of a range code 4 transmitter is 150 inwc.
Therefore, the normal static pressure effect for each transmitter is calculated with the following equation:
138 inwc  1020 psia           150 inwc  1020 psia norSPE xmtr = +/- 0.50%                        + 0.20%
108 inwc  1000 psia           108 inwc  1000 psia norSPE xmtr = +/- 0.94% Span

RNP-I/INST-1070 Revision 11 Page 50 of 104 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 +/- 0.50% Reading 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 +/- 0.20% Upper Range Limit per 1000 psi, and the Upper Range Limit of a range code 4 transmitter is 150 inwc.
Therefore, the accident static pressure effect for each transmitter is calculated with the following equation:
138 inwc  1100 psia           150 inwc  1100 psia accSPE xmtr = +/- 0.50%                         + 0.20%
108 inwc  1000 psia           108 inwc  1000 psia accSPE xmtr = +/- 1.01% Span Note that due to the pressure range of interest in the EOPs, the accSPE xmtr value is also applicable during normal containment conditions when in the EOPs. Thus, eopSPE xmtr = accSPE xmtr = +/- 1.01% 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.
PSE xmtr = N/A

RNP-I/INST-1070 Revision 11 Page 51 of 104 6.6.9 Normal Transmitter Total Device Uncertainty (norTDUxmtr)
Per EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty for normal environmental conditions is computed using the following equation:
2           2           2      2           2              2 norTDU xmtr = +/- (CAL xmtr + MTE xmtr ) + RA xmtr + DR xmtr + norTE xmtr + norSPE xmtr
                  + DR xmtrBIAS Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, 2          2            2            2 norTDU xmtr = +/- CAL xmtr + AD xmtr + norTE xmtr + norSPE xmtr + AD xmtrBIAS norTDU xmtr = +/- 0.50 2 + 1.044 2 + 1.232 + 0.94 2  0.227 norTDU xmtr = +/- 1.93% Span,  0.23% Span 6.6.10 Normal Transmitter Total Device Uncertainty (eopTDUxmtr) for EOPs Per EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty for normal environmental conditions for EOPs is computed using the following equation:
eopTDU xmtr = +/-
2          2          2           2           2             2 (CAL xmtr + MTE xmtr ) + RA xmtr + DR xmtr + eopTE xmtr + eopSPE xmtr                +
DR xmtrBIAS Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, 2             2            2 eopTDU xmtr = +/-   CAL2 + AD xmtr + eopTE xmtr + eopSPE xmtr + AD xmtrBIAS eopTDU xmtr = +/- 0.50 2 + 1.044 2 + 2.16 2 + 1.012  0.227 eopTDU xmtr = +/- 2.65% Span,  0.23% Span 6.6.11 Accident Transmitter Total Device Uncertainty (accTDUxmtr)
Per EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty for accident conditions is computed using the following equation:

RNP-I/INST-1070 Revision 11 Page 52 of 104 2          2          2          2             2 accTDU xmtr = +/- (CAL xmtr + MTE xmtr ) + RA xmtr + DR xmtr + accSPE xmtr
                   + DR xmtrBIAS Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, 2              2 accTDU xmtr = +/- CAL2 + AD xmtr + accSPE xmtr + AD xmtrBIAS accTDU xmtr = +/- 0.50 2 + 1.044 2 + 1.012  0.23 accTDU xmtr = +/- 1.54% Span,  0.23% Span 6.6.12 Transmitter As Found Tolerance (AFTxmtr)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Found Tolerance (AFT) is computed using the following equation:
2         2            2 AFT xmtr = +/- CAL xmtr + DR xmtr + MTE xmtr AFT xmtr = +/- 0.50 2 + 0.282 + 0.50 2 AFT xmtr = +/- 0.76% Span Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the AFT, therefore, 2         2 AFT xmtr = +/- CAL xmtr + AD xmtr AFT xmtr = +/- 0.50 2 + 1.044 2 AFT xmtr = +/- 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 AFT xmtr value of +/- 0.76% Span is less than, i.e., more conservative than, the above calculated AFT xmtr value of +/- 1.16% Span. For conservatism, AFT xmtr = +/- 0.76% Span will be retained.

RNP-I/INST-1070 Revision 11 Page 53 of 104 6.6.13 Transmitter As Left Tolerance (ALTxmtr)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Left Tolerance (ALT) is computed using the following equation:
ALT xmtr = CAL xmtr ALT xmtr = +/- 0.50% Span Error Contributor               Value            Type             Section RA                 +/- 0.14% Span         Random              6.6.1 CAL                +/- 0.50% Span         Random              6.6.2 DR                 +/- 0.28% Span         Random              6.6.3
                                +/- 1.044% Span        Random AD                                                          6.6.3 0.227% Span          Bias MTE                +/- 0.50% Span         Random              6.6.4 ATE                +/- 3.97% Span         Random              6.1.1 ARE                +/-3 .08% Span         Random              6.1.3 SE                +/- 0.69% Span         Random               6.2 eopTE                +/- 2.16% Span         Random              6.6.5 norTE               +/- 1.23% Span         Random              6.6.5 norSPE               +/- 0.94% Span         Random              6.6.6 accSPE               +/- 1.01% Span         Random              6.6.7 As Left Tolerance (ALT)       +/- 0.50% Span         Random             6.6.13 As Found Tolerance (AFT)       +/- 0.76% Span         Random             6.6.12 Total Device Uncertainty      +/- 2.65% Span         Random (EOP)                                                       6.6.10 0.23% Span           Bias Total Device Uncertainty      +/- 1.93 %Span         Random (non-accident)                                                    6.6.9 0.23% Span           Bias Total Device Uncertainty      +/- 1.54% Span         Random (accident)                                                     6.6.11 0.23% Span           Bias Transmitter Uncertainty Summary

RNP-I/INST-1070 Revision 11 Page 54 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is utilized to compute the repeatability portion of the comparator reference accuracy:
RA comp       0.50% Span Repeatability = +/-           =+/-               = +/- 0.29% Span 3              3 Therefore, RA comp = +/- 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 EGR-NGGC-0153 (Reference 4.6.1), 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 (EGR-NGGC-0153 (Reference 4.6.1)). Therefore, the default value of +/- 1.00% Span is used for comparator drift for the NUS and Hagan comparators.
DR comp = +/- 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.

RNP-I/INST-1070 Revision 11 Page 55 of 104 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:
5 Vdc MTE comp = +/- (0.25% Reading )            = +/- 0.31% Span 4 Vdc 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&deg;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&deg;F (23.33&deg;C) is used to compute the comparator temperature effect. Therefore, 23.33&deg;C TE comp = +/- 0.04% Span 1&deg;C TE comp = +/- 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, PSE comp = N/A 6.7.7 Comparator Total Device Uncertainty (TDUcomp)
Total Device Uncertainty is computed using the following equation:
TDU comp = +/-    (CAL  comp + MTE comp ) + RA comp + DR comp + TE comp 2          2           2          2 TDU comp = +/- 1.61% Span

RNP-I/INST-1070 Revision 11 Page 56 of 104 6.7.8 Comparator As Found Tolerance (AFTcomp)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Found Tolerance (AFT) is computed using the following equation:
2        2           2 AFT comp = +/- CAL comp + DR comp + MTE comp AFT comp = +/- 1.16% Span 6.7.9 Comparator As Left Tolerance (ALTcomp)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Left Tolerance (ALT) is computed using the following equation:
ALT comp = CALcomp ALT comp = +/- 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
                                +/- 1.61% Span         Random             6.7.7 (non-accident)
Comparator Module Uncertainty Summary

RNP-I/INST-1070 Revision 11 Page 57 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to compute the repeatability portion of the NUS EIP isolator reference accuracy:
RA isol     0.10% Span Repeatability = +/-          =+/-              = +/- 0.06% Span 3            3 For conservatism, Repeatability = +/- 0.06% P Span will be assigned to both the NUS 800 and NUS EIP isolators.
Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to compute the hysteresis portion of both the NUS 800 and NUS EIP isolator reference accuracy:
RA isol      0.10% Span Hysteresis = +/-         =+/-               = +/- 0.06% Span 3              3 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.
RA isol = +/- 0.06 2 + 0.06 2 RA isol = +/-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 [EGR-NGGC-0153 (Reference 4.6.1)].
Therefore,

RNP-I/INST-1070 Revision 11 Page 58 of 104 DR isol = +/- 1.00% Span NUS 800 Isolator Drift (DR 800isol )
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, DR 800isol = +/-
1.00% Span will be retained.
NUS EIP Isolator Drift (DR EIPisol )
Per Hagan vendor manual 728-589-13 (Reference 4.4.1), no drift uncertainty for the NUS EIP isolator is specified. Per EGR-NGGC-0153 (Reference 4.6.1), 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 DR EIPisol ,
DR EIPisol = +/- 1.67 (1.0)2 DR EIPisol = +/- 1.29% Span 6.8.4 Isolator M&TE Effect (MTE isol )
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:
5 Vdc 2
MTE isol = +/- (2 )(0.25% Reading )
4 Vdc MTE isol = +/- 0.44% Span

RNP-I/INST-1070 Revision 11 Page 59 of 104 6.8.5 Isolator Temperature Effect (TEisol)
Per Hagan vendor manual 728-589-13 (Reference 4.4.1), the NUS EIP isolator temperature effect is +/- 0.01% full scale/&deg;C. Per Reference 4.4.1, the NUS 800 isolator temperature effect is less than +/- 0.50% of output full scale per 50&deg;F for module gains less than 1.7.
Per Design Input 5.8, a change in temperature of 42&deg;F (23.33&deg;C) is used to compute the isolator temperature effect for normal conditions, and a change in temperature of 70&deg;F.
NUS EIP Isolator Temperature Effect for Normal Conditions (norTE EIPisol )
For a temperature change of 42&deg;F (23.33&deg;C), norTE EIPisol is computed as follows:
5 Vdc        100% Span  23.33&deg;C norTE EIPisol = +/- 0.01% Full Scale 100% Full Scale  4 Vdc  1&deg;C norTE EIPisol = +/- 0.29% Span NUS 800 Isolator Temperature Effect for Normal Conditions (norTE 800isol )
For a temperature change of 42&deg;F, norTE 800isol is computed as follows:
5 Vdc        100% Span  42&deg;F norTE 800isol = +/- 0.50% Full Scale 100% Full Scale  4 Vdc  50&deg;F norTE 800isol = +/- 0.53% Span NUS EIP Isolator Temperature Effect for Accident Conditions (accTE EIPisol )
For a temperature change of 70&deg;F (38.89&deg;C), accTE EIPisol is computed as follows:
5 Vdc        100% Span  38.89&deg;C accTE EIPisol = +/-0.01% Full Scale 100% Full Scale  4 Vdc  1&deg;C accTE EIPisol = +/-0.49% Span NUS 800 Isolator Temperature Effect for Accident Conditions (accTE 800isol )
For a temperature change of 70&deg;F, accTE 800isol is computed as follows:
5 Vdc        100% Span  70&deg;F accTE 800isol = +/-0.50% Full Scale 100% Full Scale  4 Vdc  50&deg;F accTE 800isol = +/-0.88% Span

RNP-I/INST-1070 Revision 11 Page 60 of 104 6.8.6 Isolator Power Supply Effect (PSEisol)
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, PSE isol = N/A 6.8.7 Isolator Total Device Uncertainty (TDUisol)
NUS EIP Isolator TDU for Normal conditions (norTDU EIPisol )
Per EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty is computed using the following equation:
norTDU EIPisol = +/-  (CALisol + MTE isol )2 + RA isol 2 + DR EIPisol 2 + norTE EIPisol 2 norTDU EIPisol = +/-  (0.50 + 0.44)2 + 0.082 + 1.29 2 + 0.29 2 norTDU EIPisol = +/- 1.62% Span NUS 800 Isolator TDU for Normal Conditions (norTDU 800isol )
Per EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty is computed using the following equation:
norTDU 800isol = +/-  (CALisol + MTE isol )2 + RA isol 2 + DR 800isol 2 + norTE 800isol 2 norTDU 800isol = +/-  (0.50 + 0.44)2 + 0.082 + 1.00 2 + 0.532 norTDU 800isol = +/- 1.47% Span NUS EIP Isolator TDU for Accident Conditions (accTDU EIPisol )
Per EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty is computed using the following equation:
accTDU EIPisol = +/-  (CALisol + MTE isol )2 + RA isol 2 + DR EIPisol 2 + accTE EIPisol 2 accTDU EIPisol = +/-  (0.50 + 0.44)2 + 0.082 + 1.29 2 + 0.49 2 accTDU EIPisol = +/- 1.67% Span

RNP-I/INST-1070 Revision 11 Page 61 of 104 NUS 800 Isolator TDU for Accident Conditions (accTDU 800isol )
Per EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty is computed using the following equation:
accTDU 800isol = +/-   (CALisol + MTE isol )2 + RA isol 2 + DR 800isol 2 + accTE800isol 2 accTDU 800isol = +/-   (0.50 + 0.44)2 + 0.082 + 1.002 + 0.882 accTDU 800isol = +/- 1.63% Span For conservatism, norTDU EIPisol , norTDU 800isol , and accTDU 800isol will be assigned the accTDU EIPisol 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 (AFT 800isol )
Per EGR-NGGC-0153, the As Found Tolerance (AFT) is computed using the following equation:
2           2           2 AFT 800isol = +/- CAL isol + DR 800isol + MTE isol AFT 800isol = +/- 0.50 2 + 1.00 2 + 0.44 2 AFT 800isol = +/- 1.20% Span NUS EIP Isolator As Found Tolerance (AFT 800isol )
Per EGR-NGGC-0153 (Reference 4.6.1), the As Found Tolerance is computed using the following equation:
2           2           2 AFT EIPisol = +/- CALisol + DR EIPisol + MTE isol AFT EIPisol = +/- 0.50 2 + 1.29 2 + 0.44 2 AFT EIPisol = +/- 1.45% Span The current AFT EIPisol value of +/- 1.20% Span is less than, i.e., more conservative than, the above calculated AFT EIPisol value of +/- 1.45% Span. For conservatism, AFT EIPisol = +/- 1.20% Span will be retained.

RNP-I/INST-1070 Revision 11 Page 62 of 104 6.8.9 Isolator As Left Tolerance (ALTisol)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Left Tolerance (ALT) is computed using the following equation:
ALT 800isol = CALisol = +/- 0.50% Span ALT EIPisol = CAL isol = +/- 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 DR 800isol             +/- 1.00% Span        Random            6.8.3 DR EIPisol             +/- 1.29% Span        Random            6.8.3 MTE                   +/- 0.44% Span        Random            6.8.4 norTE 800isol             +/- 0.53% Span        Random            6.8.5 norTE EIPisol             +/- 0.29% Span        Random            6.8.5 accTE 800isol             +/- 0.88% Span        Random            6.8.5 accTE EIPisol             +/-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
                                       +/- 1.67% Span        Random            6.8.7 (accident)
Total Device Uncertainty
                                       +/-1.67% Span         Random            6.8.7 (non-accident)
Isolator Module Uncertainty Summary Note: RA, CAL, MTE, ALT, and AFT values are equalvalent for both isolators.

RNP-I/INST-1070 Revision 11 Page 63 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is utilized to compute the repeatability portion of the indicator reference accuracy:
RA ind       2.00% Span Repeatability = +/-           =+/-              = +/- 1.15% Span 3              3 Therefore, RA ind = +/- 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 EGR-NGGC-0153 (Reference 4.6.1), the time interval between calibrations is 22.5 month (18 months +
25%), and the following equation is used to compute the indicator drift:
22.5 months DR ind = +/- 1.00% Span 12 months DR ind = +/- 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, AD ind = +/- 1.792% Span

RNP-I/INST-1070 Revision 11 Page 64 of 104 6.9.4 Indicator M&TE Effect (MTE ind )
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:
5 Vdc MTE ind = +/- (0.25% Reading )          = +/- 0.31% Span 4 Vdc 6.9.5 Indicator Temperature Effect (TEind)
Per Attachment D, the indicator temperature effect is specified as +/-0.10% Span per 1&deg;C change from the temperature at the time of calibration. Per Design Input 5.14, a change in temperature of 11.1&deg;C is used to compute the indicator temperature effect.
11.1&deg;C TE ind = +/- 0.10% Span 1&deg;C TE ind = +/- 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.
PSE ind = N/A 6.9.7 Indicator Readability (RDind)
Per EGR-NGGC-0153 (Reference 4.6.1), 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, 2%  100% Span RD ind = +/-                  = +/- 1.00% Span 2  100% 

RNP-I/INST-1070 Revision 11 Page 65 of 104 6.9.8 Indicator Total Device Uncertainty (TDUind)
Per EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty is computed using the following equation:
TDU ind = +/-   (CAL ind + MTE ind )2 + RA ind 2 + DR ind 2 + TE ind 2 + RD ind 2 TDU ind = +/-   (2.00 + 0.31)2 + 1.15 2 + 1.37 2 + 1.112 + 1.00 2 TDU ind = +/- 3.28% Span Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, 2        2         2          2 TDU ind = +/- CALind + ADind + TE ind + RD ind TDU ind = +/- 2.00 2 + 1.792 2 + 1.112 + 1.00 2 TDU ind = +/- 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 EGR-NGGC-0153 (Reference 4.6.1), the Total Device Uncertainty for EOP setpoints is computed using the following equation:
eopTDU ind = +/-    (CALind + MTE ind )2 + RA ind 2 + DR ind 2 + TE ind 2 eopTDU ind = +/-    (2.00 + 0.31)2 + 1.15 2 + 1.37 2 + 1.112 eopTDU ind = +/- 3.13% Span Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the TDU, therefore, 2         2          2 eopTDU ind = +/- CALind + ADind + TE ind eopTDU ind = +/- 2.00 2 + 1.792 2 + 1.112 eopTDU ind = +/- 2.91% Span

RNP-I/INST-1070 Revision 11 Page 66 of 104 6.9.10 Indicator As Found Tolerance (AFTind)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Found Tolerance (AFT) is computed using the following equation:
2          2        2 AFT ind = +/- CAL ind + DR ind + MTE ind AFT ind = +/- 2.00 2 + 1.37 2 + 0.312 AFT ind = +/- 2.44% Span Per Design Input 5.27, AD may replace RA, MTE, and DR as a single value when calculating the AFT, therefore, 2          2 AFT ind = +/- CALind + ADind AFT ind = +/- 2.00 2 + 1.792 2 AFT ind = +/- 2.69% Span The current AFT ind value of +/- 2.44% Span is less than, i.e., more conservative than, the above calculated AFT ind value of    +/- 2.69% Span. Therefore, for conservatism, AFT ind = +/- 2.44% Span will be retained.

RNP-I/INST-1070 Revision 11 Page 67 of 104 6.9.11 Indicator As Left Tolerance (ALTind)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Left Tolerance (ALT) is computed using the following equation:
ALT ind = CALind ALT ind = +/- 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       +/- 2.91% Span        Random             6.9.9 (EOP)
Total Device Uncertainty       +/- 3.07% Span        Random             6.9.8 (non-accident)
Indicator Uncertainty Summary

RNP-I/INST-1070 Revision 11 Page 68 of 104 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 4.7.15, 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 +/- (0.3% of reading + 3 digits). Therefore, the recorder Reference Accuracy (RA rec ) is calculated as follows:
RA rec      = +/- (0.3% Reading + 3 digits)
RA rec      = +/- (0.3% x 5 Vdc + 3 digits)
RA rec      = +/- (0.015 Vdc + 0.003 Vdc) = +/- 0.018 Vdc 0.018 Vdc RA rec      =+/-               100% Span 4 Vdc RA rec      = +/- 0.45% 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 11 Page 69 of 104 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, DR rec = 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:
5 Vdc MTE rec = +/- (0.25% Reading )         = +/- 0.31% Span 4 Vdc 6.10.5 Recorder Temperature Effect (TErec)
Per Reference 4.7.15, the Recorder Ambient Temperature Effect is given as +/- (0.1% of reading + 1 digit) for ambient temperature variation of 10&deg;C (18&deg;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&deg;F is bounding for this application. Therefore, the Recorder Temperature Effect (TE rec ) is calculated as follows:
TE rec     = +/- (0.1% Reading + 1 digit) (20&deg;F/18&deg;F)
TE rec     = +/- (0.1% x 5 Vdc + 1 digit) (20&deg;F/18&deg;F)
TE rec     = +/- (0.005 Vdc + 0.001 Vdc) (20&deg;F/18&deg;F) = +/- 0.0067 Vdc 0.0067 Vdc TE rec     =+/-                100% Span 4 Vdc TE rec     = +/- 0.17% Span 6.10.6 Recorder Power Supply Effect (PSErec)
Per Reference 4.7.15, the power supply effect for a variation within 90 to 132 Vac is less than 1 digit. Per Reference 4.2.1, power variation will remain within this band. Per EGR-

RNP-I/INST-1070 Revision 11 Page 70 of 104 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, PSE rec = N/A 6.10.7 Recorder Readability (RDrec)
Per Reference 4.7.15, 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, 0.001 Vdc RD rec = +/-              100% Span = +/- 0.03% Span 4.0 Vdc 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, RD rec = N/A 6.10.8 Recorder Total Device Uncertainty (TDUrec)
Total Device Uncertainty is computed using the following equation:
TDU rec = +/-   (CAL rec + MTE rec )2 + RA rec 2 + TE rec 2 TDU rec = +/-   (0.50 + 0.31)2 + 0.45 2 + 0.17 2 TDU rec = +/- 0.94% Span 6.10.9 Recorder As-Found Tolerance (AFTrec)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Found Tolerance (AFT) is computed using the following equation:
2           2 AFT rec = +/- CAL rec + MTE rec AFT rec = +/- 0.59% Span

RNP-I/INST-1070 Revision 11 Page 71 of 104 6.10.10 Recorder As Left Tolerance (ALTrec)
Per EGR-NGGC-0153 (Reference 4.6.1), the As Left Tolerance (ALT) is computed using the following equation:
ALT rec = CAL rec ALT rec = +/- 0.50% Span Error Contributor               Value            Type             Section RA                 +/- 0.45% 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                 +/- 0.15% 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
                                    +/- 0.94% Span        Random             6.10.8 (non-accident)
Recorder Uncertainty Summary

RNP-I/INST-1070 Revision 11 Page 72 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the indicator is computed with the following equation:
2          2          2 TLU ind = +/- norTDU xmtr + TDU isol + TDU ind + norPME + AD xmtrBIAS TLU ind = +/- 1.932 + 1.67 2 + 3.07 2 + norPME  0.23 TLU ind = +/- 3.99% Span + norPME% Span  0.23% Span Fluid        Fluid     Random        AD xmtrBIAS  Positive    Negative Height       Height Uncertainty Uncertainty        norPME      norPME
(% Span)        (in.)   (% Span)        (% Span)   (% Span)    (% Span) 0.00         0.00       +/-3.99          0.23       1.83       8.38 16.00        22.96       +/-3.99          0.23       1.06       8.37 30.00        43.05       +/-3.99          0.23       NA         9.81 50.00        71.75       +/-3.99          0.23       NA         10.55 75.00       107.63       +/-3.99          0.23       NA         12.39 100.00       143.50       +/-3.99          0.23       NA         14.01 Combined Uncertainties Fluid         Fluid         Positive      Negative Height       Height          TLU            TLU
(% Span)         (in.)       (% Span)      (% Span) 0.00         0.00           5.82         12.60 16.00        22.96           5.05         12.59 30.00        43.05           3.99         14.03 50.00        71.75           3.99         14.77 75.00       107.63           3.99         16.61 100.00       143.50           3.99         18.23

RNP-I/INST-1070 Revision 11 Page 73 of 104 7.1.2 Total Loop Uncertainty - Input to ERFIS Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty at the input to ERFIS is computed with the following equation:
2            2           2 TLU ERFIS = +/- norTDU xmtr + TDU isol + TDU isol + norPME + AD xmtrBIAS TLU ERFIS = +/- 1.932 + 1.67 2 + 1.67 2 + norPME  0.23 TLU ERFIS = +/- 3.05% Span + norPME% Span  0.23% Span Fluid         Fluid        Random        AD xmtrBIAS   Positive     Negative Height        Height     Uncertainty Uncertainty        norPME       norPME
(% Span)         (in.)      (% Span)        (% Span)    (% Span)     (% Span) 0.00           0.00         +/-3.05           0.23        1.83        8.38 16.00         22.96         +/-3.05           0.23        1.06        8.37 30.00         43.05         +/-3.05           0.23        NA          9.81 50.00         71.75         +/-3.05           0.23        NA          10.55 75.00        107.63         +/-3.05           0.23        NA          12.39 100.00        143.50         +/-3.05           0.23        NA          14.01 Combined Uncertainties Fluid         Fluid        Positive    Negative Height         Height         TLU         TLU
(% Span)          (in.)     (% Span) (% Span) 0.00          0.00         4.88       11.66 16.00         22.96         4.11       11.65 30.00         43.05         3.05       13.09 50.00         71.75         3.05       13.83 75.00        107.63         3.05       15.67 100.00        143.50         3.05       17.29

RNP-I/INST-1070 Revision 11 Page 74 of 104 7.1.3 Total Loop Uncertainty - Recorder FR-478, 488, & 498 Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the recorder is computed with the following equation:
2           2         2 TLU rec = +/- norTDU xmtr + TDU isol + TDU rec + norPME + AD xmtrBIAS TLU rec = +/- 1.932 + 1.67 2 + 0.94 2 + norPME  0.23 TLU rec = +/- 2.72% Span + norPME% Span  0.23% Span Fluid        Fluid        Random       AD xmtrBIAS  Positive    Negative Height       Height     Uncertainty Uncertainty norPME           norPME
(% Span)         (in)      (% Span)       (% Span) (% Span)      (% Span) 0.00          0.00        +/-2.72          0.23       1.83        8.38 16.00         22.96        +/-2.72          0.23       1.06        8.37 30.00         43.05        +/-2.72          0.23       NA          9.81 50.00         71.75        +/-2.72          0.23       NA         10.55 75.00        107.63        +/-2.72          0.23       NA         12.39 100.00        143.50        +/-2.72          0.23       NA         14.01 Combined Uncertainties Fluid         Fluid       Positive  Negative Height        Height        TLU        TLU
(% Span)          (in)     (% Span) (% Span) 0.00          0.00        4.55      11.33 16.00         22.96        3.78      11.32 30.00         43.05        2.72      12.76 50.00         71.75        2.72      13.50 75.00        107.63        2.72      15.34 100.00        143.50        2.72      16.96

RNP-I/INST-1070 Revision 11 Page 75 of 104 7.1.4 Total Loop Uncertainty - High Level Alarm LC-474, 475, 476, 484, 485, 486, 494, 495, & 496 (switch 2)
Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the comparators which provide the High Steam Generator Level alarm is computed with the following equation:
2            2 TLU comp = +/- norTDU xmtr + TDU comp + norPME @ 75% Level + AD xmtrBIAS TLU comp = +/- 1.932 + 1.612  12.39  0.23 TLU comp = +/- 2.51% Span  12.62% Span TLU comp = + 2.51% Span, 15.13% Span 7.1.5 Total Loop Uncertainty - Low Low Level Alarm LC-474A, 475A, 476A, 484A, 485A, 486A, 494A, 495A, & 496A (switch 2)
Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the comparators which provide the Low Low Steam Generator Level alarm is computed with the following equation:
2            2 TLU comp = +/- norTDU xmtr + TDU comp + norPME @16% Level + AD xmtrBIAS TLU comp = +/- 1.932 + 1.612 + 1.06  8.37  0.23 TLU comp = +/- 2.51% Span +1.06% Span  8.60% Span TLU comp = +3.57% Span, 11.11% Span 7.1.6 Total Loop Uncertainty - Low Level Alarm LC-474B, 475B, 484B, 485B, 494B, 495B Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the comparators which provide the Low Steam Generator Level alarm are computed with the following equation:
2            2 TLU comp = +/- norTDU xmtr + TDU comp + norPME @ 30% + AD xmtrBIAS TLU comp = +/- 1.932 + 1.612  9.81  0.23

RNP-I/INST-1070 Revision 11 Page 76 of 104 TLU comp = +/- 2.51% Span  10.04% Span TLU comp = +2.51% Span, 12.55% Span 7.1.7 Total Loop Uncertainty - Input to AMSAC Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the input to AMSAC are computed with the following equation:
2         2 TLU AMSAC = +/- norTDU xmtr + TDU isol + norPME + AD xmtrBIAS TLU AMSAC = +/- 1.932 + 1.67 2 + norPME  0.23 TLU AMSAC = +/- 2.55% Span + norPME% Span  0.23% Span Fluid         Fluid      Random      AD xmtrBIAS     Positive      Negative Height        Height   Uncertainty Uncertainty        norPME        norPME
(% Span)         (in.)    (% Span)     (% Span)       (% Span)      (% Span) 0.00           0.00       +/-2.55         0.23          1.83         8.38 16.00         22.96       +/-2.55         0.23          1.06         8.37 30.00         43.05       +/-2.55         0.23          NA           9.81 50.00         71.75       +/-2.55         0.23          NA           10.55 75.00        107.63       +/-2.55         0.23          NA           12.39 100.00        143.50       +/-2.55         0.23          NA           14.01 Combined Uncertainties Fluid      Fluid     Positive      Negative Height      Height       TLU            TLU
(% Span)       (in.)   (% Span) (% Span) 0.00       0.00       4.38         11.16 16.00      22.96       3.61         11.15 30.00      43.05       2.55         12.59 50.00      71.75       2.55         13.33 75.00     107.63       2.55         15.17 100.00     143.50       2.55         16.79

RNP-I/INST-1070 Revision 11 Page 77 of 104 7.1.8 Total Loop Uncertainty for use in the EOPs - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, AND 496 Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the indicator, for normal conditions (15 psia to 1100 psia SG pressure) and 88&deg;F to 190&deg;F (Ref Leg temp), is computed with the following equation:
2          2            2 TLU ind = +/- eopTDU xmtr + TDU isol + eopTDU ind + eopPME + AD xmtrBIAS TLU ind = +/- 2.652 + 1.67 2 + 2.912 + eopPME  0.23 TLU ind = +/- 4.28% Span + eopPME% Span  0.23% Span Note: The eopPME values were determined in Section 6.4.3.
Random       AD xmtrBIAS      Positive        Negative Fluid Height Fluid Height Uncertainty   Uncertainty       eopPME          eopPME
(% Span)             (in.)
(% Span)      (% Span)        (% Span)        (% Span) 0.00             0.00           +/- 4.28         0.23            3.84           4.71 16.00            22.96           +/- 4.28         0.23            3.41           1.26 30.00            43.05           +/- 4.28         0.23            7.20           2.45 50.00            71.75           +/- 4.28         0.23           12.60           4.16 75.00           107.63           +/- 4.28         0.23           19.36           6.30 100.00           143.50           +/- 4.28         0.23           26.12           8.44 Combined Uncertainties Fluid         Fluid     Positive      Negative Height       Height       TLU           TLU
(% Span)         (in)    (% Span)      (% Span) 0.00         0.00       8.12         9.22 16.00        22.96       7.69         5.77 30.00        43.05      11.48         6.96 50.00        71.75      16.88         8.67 75.00       107.63      23.64         10.81 100.00       143.50      30.40         12.95

RNP-I/INST-1070 Revision 11 Page 78 of 104 7.2 TOTAL LOOP UNCERTAINTY - ACCIDENT 7.2.1 Total Loop Uncertainty - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, & 496 Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the indicator is computed with the following equation:
TLU ind = +/- accTDU xmtr 2 + TDU isol 2 + TDU ind 2 + ATE xmtr 2 + ARE xmtr 2 + IR + accPME
              + AD xmtrBIAS TLU ind = +/- 1.54 2 + 1.67 2 + 3.07 2 + 3.97 2 + 3.082 + IR + accPME  0.23 TLU ind = +/- 6.31% 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        Fluid        Random        AD xmtrBIAS                    Posititve     Negative IR Height       Height      Uncertainty Uncertainty                        accPME        accPME
(% Span)
(% Span)         (in.)      (% Span)        (% Span)                     (% Span)      (% Span) 0.00         0.00         +/-6.31           0.23            2.19        13.71         11.72 16.00        22.96         +/-6.31           0.23            2.19        12.65         7.94 30.00        43.05         +/-6.31           0.23            2.19        10.24         10.13 50.00        71.05         +/-6.31           0.23            2.19        14.08         11.21 75.00       107.63         +/-6.31           0.23            2.19        20.93         13.26 100.00        143.5         +/-6.31           0.23            2.19        27.78         15.31 Combined Uncertainties Fluid         Fluid         Posititve     Negative Height        Height           TLU           TLU
(% Span)         (in.)       (% Span) (% Span) 0.00          0.00           22.21        18.26 16.00         22.96           21.15        14.48 30.00         43.05           18.74        16.67 50.00         71.05           22.58        17.75 75.00        107.63           29.43        19.80 100.00         143.5           36.28        21.85

RNP-I/INST-1070 Revision 11 Page 79 of 104 7.2.2 Total Loop Uncertainty - Recorder FR-478, 488, & 498 Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the recorder is computed with the following equation:
2            2          2           2             2 TLU rec = +/- accTDU xmtr + TDU isol + TDU rec + ATE xmtr + ARE xmtr + IR + accPME
               + AD xmtrBIAS TLU rec = +/- 1.54 2 + 1.67 2 + 0.94 2 + 3.97 2 + 3.08 2 + IR + accPME  0.23 TLU rec = +/- 5.59% 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        Fluid        Random        AD xmtrBIAS                     Positive     Negative IR Height       Height      Uncertainty    Uncertainty                      accPME       accPME
(% Span)
(% Span)         (in.)      (% Span)        (% Span)                      (% Span)     (% Span) 0.00        0.00          +/-5.59            0.23           2.19         13.71        11.72 16.00       22.96         +/-5.59            0.23           2.19         12.65        7.94 30.00       43.05         +/-5.59            0.23           2.19         10.24        10.13 50.00       71.75         +/-5.59            0.23           2.19         14.08        11.21 75.00      107.63         +/-5.59            0.23           2.19         20.93        13.26 100.00      143.50         +/-5.59            0.23           2.19         27.78        15.31 Combined Uncertainties Fluid          Fluid           Positive         Negative Height        Height            TLU               TLU
(% Span)           (in.)        (% Span)          (% Span) 0.00           0.00            21.49            17.54 16.00         22.96            20.43            13.76 30.00         43.05            18.02            15.95 50.00         71.75            21.86            17.03 75.00        107.63            28.71            19.08 100.00        143.50            35.56            21.13

RNP-I/INST-1070 Revision 11 Page 80 of 104 7.2.3 Total Loop Uncertainty - Input to ERFIS Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty at the input to ERFIS is computed with the following equation:
TLU ERFIS    =    +/- accTDU xmtr 2 + TDU isol 2 + TDU isol 2 + ATE xmtr 2 + ARE xmtr 2 +   IR   +
accPME
                    + AD xmtrBIAS TLU ERFIS = +/- 1.54 2 + 1.67 2 + 1.67 2 + 3.97 2 + 3.08 2 + IR + accPME  0.23 TLU ERFIS = +/- 5.76% 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        Fluid        Random         ADxmtrBIAS                    Positive         Negative IR Height       Height      Uncertainty Uncertainty                        accPME           accPME
(% Span)
(% Span)        (in.)      (% Span)         (% Span)                    (% Span)         (% Span) 0.00          0.00         +/- 5.76           0.23           2.19          13.71          11.72 16.00        22.96         +/- 5.76           0.23           2.19          12.65           7.94 30.00        43.05         +/- 5.76           0.23           2.19          10.24           10.13 50.00        71.75         +/- 5.76           0.23           2.19          14.08          11.21 75.00       107.63         +/- 5.76           0.23           2.19          20.93          13.26 100.00       143.50         +/- 5.76           0.23           2.19          27.78           15.31 Combined Uncertainties Fluid           Fluid         Positive         Negative Height         Height       Uncertainty      Uncertainty
(% Span)           (in.)       (% Span)         (% Span) 0.00           0.00            21.66           17.71 16.00          22.96           20.60           13.93 30.00          43.05           18.19           16.12 50.00          71.75           22.03           17.20 75.00         107.63           28.88           19.25 100.00         143.50           35.73           21.30

RNP-I/INST-1070 Revision 11 Page 81 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the comparators that provide the Low Low Steam Generator Level Reactor Trip is computed with the following equation:
TLU comp = +/- accTDU xmtr 2 + TDU comp 2 + ATE xmtr 2 + IR + accPME @ 0% Level
               + AD xmtrBIAS TLU comp = +/- 1.54 2 + 1.612 + 3.97 2 + 2.19 + 5.79  11.72  0.23 TLU comp = +/- 4.55% Span + 7.98% Span  11.95% Span TLU comp = +12.53% Span , 16.50% 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 EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the comparators that provide the Low Low Steam Generator Level Reactor Trip is computed with the following equation:
TLU comp = +/- norTDU xmtr 2 + TDU comp 2 + SE xmtr 2 + norPME @ 0% Level + MDDPb + AD xmtrBIAS From Section 5.18, MDDPb = +4.88% Span for accident conditions.
TLU comp = +/- 1.932 + 1.612 + 0.69 2 + 1.83  8.38 + 4.88  0.23 TLU comp = +/- 2.61% Span + 6.71% Span  8.61% Span TLU comp = + 9.32% Span, 11.22% 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 11 Page 82 of 104 7.2.5 Total Loop Uncertainty for use in the EOPs - Indicator LI-474, 475, 476, 484, 485, 486, 494, 495, AND 496 Per EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the indicator is computed with the following equation. The individual error components, acceopTDU xmtr , TDU isol , TDU ind , ATE xmtr , and ARE xmtr were determined in Sections 6.6.11, 6.8.7, 6.9.9, 6.1.1, and 6.1.3, respectively.
TLU ind = +/- accTDU xmtr 2 + TDU isol 2 + TDU ind 2 + ATE xmtr 2 + ARE xmtr 2 + IR + acceopPME
             + AD xmtrBIAS TLU ind = +/- 1.54 2 + 1.67 2 + 2.912 + 3.97 2 + 3.082 + IR + acceopPME  0.23 TLU ind = +/- 6.24% 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        Fluid        Random        AD xmtrBIAS                     Posititve        Negative IR Height       Height     Uncertainty Uncertainty                        acceopPME        acceopPME
(% Span)
(% Span)        (in.)      (% Span)       (% Span)                       (% Span)         (% Span) 0.00         0.00         +/- 6.24           0.23          2.19           9.52            11.72 16.00        22.96         +/- 6.24           0.23          2.19           8.47             7.94 30.00        43.05         +/- 6.24           0.23          2.19           8.05             9.90 50.00        71.05         +/- 6.24           0.23          2.19          14.08            10.98 75.00       107.63         +/- 6.24           0.23          2.19          20.93            13.26 100.00        143.5         +/- 6.24           0.23          2.19          27.78            15.31 Combined Uncertainties Fluid         Fluid        Posititve     Negative Height        Height         TLU            TLU
(% Span)          (in.)      (% Span)      (% Span) 0.00          0.00         17.95         18.19 16.00         22.96         16.90         14.41 30.00         43.05         16.48         16.37 50.00         71.05         22.51         17.45 75.00        107.63         29.36         19.73 100.00         143.5         36.21         21.78

RNP-I/INST-1070 Revision 11 Page 83 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the total loop uncertainty associated with the comparators which provide the High Steam Generator Level Valve interlock is computed with the following equation:
TLU comp = +/- norTDU xmtr 2 + TDU comp 2 + SE xmtr 2 + norPME @ 100% Level + AD xmtrBIAS TLU comp = +/- 1.932 + 1.612 + 0.69 2 + 0.00 14.01  0.23 TLU comp = +/- 2.61% Span  14.24% Span TLU comp = + 2.61% Span , 16.85% 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the indicator Loop As Found Tolerance (LAFT ind ):
2           2        2 LAFT ind = +/- AFTxmtr + AFTisol + AFTind LAFT ind = +/- 0.76 2 + 1.20 2 + 2.44 2 LAFT ind = +/- 2.82% Span 7.4.2 Loop As Found Tolerance - Input to ERFIS Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the ERFIS Loop As Found Tolerance (LAFT ERFIS ):
2            2      2 LAFT ERFIS = +/- AFTxmtr + AFTisol + AFTisol LAFT ERFIS = +/- 0.76 2 + 1.20 2 + 1.20 2 LAFT ERFIS = +/- 1.86% Span

RNP-I/INST-1070 Revision 11 Page 84 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the comparator Loop As Found Tolerance (LAFT comp ):
2             2 LAFT comp = +/- AFTxmtr + AFTcomp LAFT comp = +/- 0.76 2 + 1.16 2 LAFT comp = +/- 1.39% Span 7.4.4 Loop As Found Tolerance - Recorder FR-478, 488, & 498 Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the recorder Loop As Found Tolerance (LAFT rec ):
2           2       2 LAFT rec = +/- AFTxmtr + AFTisol + AFTrec LAFT rec = +/- 0.76 2 + 1.20 2 + 0.59 2 LAFT rec = +/- 1.54% Span 7.4.5 Loop As Found Tolerance - Input to AMSAC Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the Loop As Found Tolerance for AMSAC (LAFT AMSAC ):
2             2 LAFT AMSAC = +/- AFTxmtr + AFTisol LAFT AMSAC = +/- 0.76 2 + 1.20 2 LAFT AMSAC = +/- 1.42% Span

RNP-I/INST-1070 Revision 11 Page 85 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the indicator Group As Found Tolerance (GAFT ind ):
2         2 GAFT ind = +/- AFTisol + AFTind GAFT ind = +/- 1.20 2 + 2.44 2 GAFT ind = +/- 2.72% Span 7.5.2 Group As Found Tolerance - Input to ERFIS Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the ERFIS Group As Found Tolerance (GAFT ERFIS ):
2        2 GAFT ERFIS = +/- AFTisol + AFTisol GAFT ERFIS = +/- 1.20 2 + 1.20 2 GAFT ERFIS = +/- 1.70% Span

RNP-I/INST-1070 Revision 11 Page 86 of 104 7.5.3 Group As Found Tolerance - Recorder FR-478, 488, & 498 Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the recorder Group As Found Tolerance (GAFT rec ):
2        2 GAFT rec = +/- AFTisol + AFTrec GAFT rec = +/- 1.20 2 + 0.59 2 GAFT rec = +/- 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the comparator Group As Found Tolerance (GAFT comp ):
GAFT comp = +/- AFT comp GAFT comp = +/- 1.16% Span 7.5.5 Group As Found Tolerance - Input to AMSAC Per EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the AMSAC Group As Found Tolerance (GAFT AMSAC ):
GAFT AMSAC = +/- AFT isol GAFT AMSAC = +/- 1.20% Span

RNP-I/INST-1070 Revision 11 Page 87 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the maximum value for this setpoint:
SP limit  AL  TLU where, SP limit = 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 16.85% Span. Per Section 7.3.1, +/- 2.61% Span of this is the random component.
Per EGR-NGGC-0153 (Reference 4.6.1), the random uncertainty may be reduced by applying the single side of interest. Therefore, the random loop uncertainty for this setpoint is +/- 2.15%
span (0.8225  2.61% Span). This results in a negative uncertainty of 16.39% Span (2.15%
Span  14.24% Span). Per Design Input 5.13, the High Steam Generator Level valve interlock setpoint limit is 97.77% Span. Therefore, SP limit  97.77% Span  16.39% Span SP limit  81.38% 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 = SP limit  Calibrated Setpoint M = 81.38% Span  75% Span M = 6.38% Span Therefore, the current High Steam Generator Level valve interlock setpoint is conservative.

RNP-I/INST-1070 Revision 11 Page 88 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the maximum value for this setpoint:
SP limit  AL  TLU
: where, SP limit = 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, SP limit  75% Span  2.28% Span SP limit  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 = SP limit  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 11 Page 89 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the minimum value for this setpoint:
SP limit  AL + TLU
: where, SP limit = 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 2.51% Span. Per Design Input 5.16, the Low Steam Generator Level alarm setpoint limit is 30% Span. Therefore, SP limit  30% Span + 2.51% Span SP limit  32.51% 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  SP limit M = 35% Span  32.51% Span M = 2.49% Span Therefore, the current alarm setpoint is conservative.

RNP-I/INST-1070 Revision 11 Page 90 of 104 Per Section 7.5.4 of this calculation, the Group As Found Tolerance (GAFT) is 1.16% Span.
Per EGR-NGGC-0153 (Reference 4.6.1), 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 1.39% Span is computed in Section 7.4.3. Per EGR-NGGC-0153 (Reference 4.6.1), the Channel Operability Limit (COL) is computed with the following equation:
COL = SP  LAFT, where SP = calibrated setpoint COL = 30% Span  1.39% Span COL = 28.61% Span

RNP-I/INST-1070 Revision 11 Page 91 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the minimum value for this setpoint:
SP limit  AL + TLU
: where, SP limit = 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 3.57% Span. Per Design Input 5.17, the Low Low Steam Generator Level alarm setpoint limit is 16% Span. Therefore, SP limit  16% Span + 3.57% Span SP limit  19.57% 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  SP limit M = 35% Span  19.57% Span M = 15.43% Span Therefore, the current alarm setpoint is conservative.

RNP-I/INST-1070 Revision 11 Page 92 of 104 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 EGR-NGGC-0153 (Reference 4.6.1), the following equation is used to calculate the minimum value for this setpoint:
SP limit  AL + TLU
: where, SP limit = 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 +/-4.55% Span, and the positive bias portion under accident conditions is +7.98% Span. Per EGR-NGGC-0153 (Reference 4.6.1), the random loop uncertainty may be reduced by applying the single side of interest. Therefore, the random loop uncertainty for this setpoint is +/-3.74% Span (4.55% Span  0.8225). Therefore, the positive total loop uncertainty associated with this setpoint is 11.72% Span .
Per Reference 4.7.3, the Low Low Steam Generator Level Reactor Trip setpoint analytical limit is 0% Span. Therefore, SP limit  0% Span + 11.72% Span SP limit  11.72% Span Per Reference 4.7.3, 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  SP limit M = 16% Span - 11.72% Span M = 4.28% Span

RNP-I/INST-1070 Revision 11 Page 93 of 104 Per Section 7.5.4 of this calculation, the Group As Found Tolerance (GAFT) is 1.16% Span.
Per EGR-NGGC-0153 (Reference 4.6.1), the Allowable Value (AV) associated with this setpoint is computed as follows:
AV  SP  GAFT, where SP = calibrated setpoint AV  16% Span  1.16% Span AV  14.84% Span The Loop As Found Tolerance (LAFT) of 1.39% Span is computed in Section 7.4.3. Per EGR-NGGC-0153 (Reference 4.6.1), the Channel Operability Limit (COL) is computed with the following equation:
COL = SP  LAFT, where SP = calibrated setpoint COL = 16% Span  1.39% Span COL = 14.61% Span Normal (variable)
Operating Margin (variable)
Setpoint (16% Span decreasing)
Group As Found Tolerance (1.16% Span)        Loop As Found Tolerance (1.39% Span)
Allowable Value ( 14.84% Span)
Channel Operability Limit (14.61% Span)
Total Loop Uncertainty (11.72% Span)
Additional Margin (4.28% Span)
Analytical Limit (0% Span)
Low Low Steam Generator Level Reactor Trip Setpoint Diagram Per Reference 4.7.3, the current Technical Specification Allowable Value is 15.36% Span and the current Technical Specification setpoint is 16% Span decreasing. The current Technical Specification setpoint and Allowable Value are conservative.

RNP-I/INST-1070 Revision 11 Page 94 of 104 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 This calculation results in no changes to the UFSAR.
8.3 Impact On Design Basis Documents This calculation impacts no design basis documents.
8.4 Impact On Other Calculations This calculation impacts the following calculations:
: 1. RNP-I/INST-1103
* The instrument uncertainty values used in RNP-I/INST-1103 Rev. 5 (Reference 4.2.4) reference this calculation. Due to changes in total loop uncertainties and the addition of a transmitter bias introduced by this calculation, calculations for EOP setpoints G.2, G.3, G.5, G.7, G.8, G.17, and G.18 within RNP-I/INST-1103 Rev. 5 require change.
: 2. RNP-I/INST-1079
* RNP-I/INST-1079 Rev. 3 (Reference 4.2.9) reference this calculation but no AOP setpoints are affected. However, RNP-I/INST-1079 Rev. 3 references RNP-I/INST-1103 regarding EOP setpoints G.2, G.5, G.7, and G.8, which are impacted (see 1.
above).
In addition, Calculations RNP-I/INST-1132, RNP-I/INST-1071 and RNP-M/MECH-1651 reference this calculation, but are not impacted by the changes made in this revision.

RNP-I/INST-1070 Revision 11 Page 95 of 104 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 11 Page 96 of 104 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 1154DP4 differential pressure transmitter.
Per Reference 4.4.3, a range code 4 transmitter has the following differential pressure ranges 0-25 to 0-150 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&deg;F, and the temperature at 1020 psia is 547&deg;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&deg;F and 550&deg;F is 7.73x10-6 in / in / &deg;F. The following equation is used to compute the thermal expansion of the Steam Generator during normal operation (100% load):
H operating = H cold [ 1 + (T operating - T cold )]
H operating = 143 inches [ 1 + 7.73x10-6(518 &deg;F - 70 &deg;F)]
H operating = 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&deg;F and saturated steam at 900 psia. The reference leg contains compressed water at a nominal temperature of 120&deg;F. The following equation is used to obtain the calibration values for the transmitter:
P C = h SG WC + (H - h ) SG SC - H SG RC where, h =       height of fluid (inches)
H =       height of measured level span = 143.5 inches SG WC     = specific gravity of fluid = 0.787341 @ 900 psia, 500&deg;F SG SC     = specific gravity of steam = 0.032034 @ 900 psia, saturated SG RC     = specific gravity of reference leg fill fluid = 0.992946 @ 900 psia, 120&deg;F, compressed

RNP-I/INST-1070 Revision 11 Page 97 of 104 Therefore, Fluid      Fluid Calibrated Height      Height        PC
(% Span)        (in)      (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 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:
900 psi 0.75% of input             = 0.675% of input 1000 psi 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.

RNP-I/INST-1070 Revision 11 Page 98 of 104 The following equation is used to compute the required transmitter output for a given differential pressure input:
4 Vdc EO =               (137.1 inwc - P ) + 1.000 Vdc 107.3 inwc 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(% Span)                0.76% Span AFT(Vdc) = +/-4 Vdc                        = +/-4 Vdc              = +/- 0.030 Vdc 100                       100 ALT(% Span)                0.50% Span ALT(Vdc) = +/-4 Vdc                        = +/-4 Vdc              = +/- 0.020 Vdc 100                       100 The calibration table for the transmitter is as follows:
Required Input        Desired Output         As Found Tolerance      As Left Tolerance (inwc)                (Vdc)                    (Vdc)                   (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 11 Page 99 of 104 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(% Span)                1.20% Span AFT(Vdc) = +/-4 Vdc                      = +/-4 Vdc                 = +/- 0.048 Vdc 100                       100 ALT  (% Span)              0 .50 % Span ALT(Vdc) = +/-4 Vdc                       = +/-4 Vdc                 = +/- 0.020 Vdc 100                        100 The calibration table for the isolator is as follows:
Required Input       Desired Output         As Found Tolerance         As Left Tolerance (Vdc)               (Vdc)                    (Vdc)                      (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 11 Page 100 of 104 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 (%)
Setpoint(Vdc) = 4 Vdc                  + 1.000 Vdc 100%
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(% Span)               1.16% Span AFT(Vdc) = +/-4 Vdc                      = +/-4 Vdc              = +/- 0.046 Vdc 100                      100 ALT(% Span)               0.50% Span ALT(Vdc) = +/-4 Vdc                      = +/-4 Vdc               = +/- 0.020 Vdc 100                      100 The following table provides calibration values for the comparators:
Setpoint      Setpoint     As Found Tolerance        As Left Tolerance
(%)         (Vdc)                (Vdc)                   (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 11 Page 101 of 104 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 (%)
Setpoint(Vdc) = 4 Vdc                  + 1.000 Vdc 100%
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(% Span)               1.16% Span AFT(Vdc) = +/-4 Vdc                      = +/-4 Vdc              = +/- 0.046 Vdc 100                      100 ALT(% Span)               0.50% Span ALT(Vdc) = +/-4 Vdc                      = +/-4 Vdc               = +/- 0.020 Vdc 100                      100 The following table provides calibration values for the comparators:
Setpoint     Setpoint     As Found Tolerance        As Left Tolerance
(%)         (Vdc)                (Vdc)                   (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 11 Page 102 of 104 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 (%)
Setpoint(Vdc) = 4 Vdc                  + 1.000 Vdc 100%
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(% Span)               1.16% Span AFT(Vdc) = +/-4 Vdc                      = +/-4 Vdc              = +/- 0.046 Vdc 100                      100 ALT(% Span)               0.50% Span ALT(Vdc) = +/-4 Vdc                      = +/-4 Vdc               = +/- 0.020 Vdc 100                      100 The following table provides calibration values for the comparators:
Setpoint      Setpoint     As Found Tolerance        As Left Tolerance
(%)         (Vdc)                (Vdc)                   (Vdc) 35          2.400          2.354 to 2.446          2.380 to 2.420 Comparator Calibration Table

RNP-I/INST-1070 Revision 11 Page 103 of 104 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:
100%
IO =         (E I  1.000 Vdc )
4 Vdc 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(% Span)               2.44% Span AFT(Vdc) = +/-4 Vdc                       = +/-4 Vdc              = +/- 0.098 Vdc 100                     100 ALT(% Span)              2.00% Span ALT(Vdc) = +/-4 Vdc                       = +/-4 Vdc              = +/- 0.080 Vdc 100                     100 The following table provides calibration values for the indicators:
Desired Input       Required Output         As Found Tolerance      As Left Tolerance (Vdc)                   (%)                    (Vdc)                   (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 11 Page 104 of 104 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:
100%
RO =          (E I  1.000 Vdc )
4 Vdc 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(% Span)                0.59% Span AFT(Vdc) = +/- 4 Vdc                      = +/- 4 Vdc               = +/- 0.024 Vdc 100                      100 ALT(% Span)               0.50% Span ALT(Vdc) = +/- 4 Vdc                      = +/- 4 Vdc               = +/- 0.020 Vdc 100                      100 The following table provides calibration values for the recorder:
Desired Input        Required Output       As Found Tolerance        As Left Tolerance (Vdc)                   (%)                   (Vdc)                    (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 11 ATTACHMENT B        Page 1 of 1 COMPARATOR DRIFT

RNP-I/INST-1070 Revision 11 ATTACHMENT C       Page 1 of 1 ROSEMOUNT DRIFT

RNP-I/INST-1070 Revision 11 ATTACHMENT D                    Page 1 of 1 INTERNATIONAL INSTRUMENTS INDICATOR DATA

RNP-I/INST-1070 Revision 11 ATTACHMENT F                         Page 1 of 2 NUS Instruments Long Term Drift Test for NUS Modules - Final Report, Executive 440 West Broadway , Idaho Falls, ID 83402 , Phone: 208-529-1000 , Fax: 208-524-9238 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.

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                   ACCURACY            DRIFT       DRIFT (%URL) 2 sigma DRIFT CLASS 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:               Work Phone: 208.524.9236 SCIENTECH - Broadway          Facsimile: 208.524.9238 440 West Broadway Idaho Falls, Idaho 83402-3638 E-208.524.9200 Front Desk       mail: LWold@scientech.com 208.524.9282 Fax

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}}