RS-04-105, Additional Information to Support Review of the Request for Technical Specification Changes Related to Primary Containment Isolation Instrumentation (Main Steam Line Flow-High)

Additional Information to Support Review of the Request for Technical Specification Changes Related to Primary Containment Isolation Instrumentation (Main Steam Line Flow-High)

ML042180210
Person / Time
Site:	Quad Cities
Issue date:	07/19/2004
From:	Simpson P Exelon Generation Co, Exelon Nuclear
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
RS-04-105 QDC-0200-I-1369
Download: ML042180210 (52)

Text

Exelon Generation www.exeloncorp.com Exelon.

4300 Winfield Road Nuclear Warrenville, IL60555 10 CFR 50.90 RS-04-105 July 19, 2004 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-001 Quad Cities Nuclear Power Station, Units 1 and 2 Facility Operating License Nos. DPR-29 and DPR-30 NRC Docket Nos. 50-254 and 50-265

Subject:

Additional Information to Support Review of the Request for Technical Specification Changes Related to Primary Containment Isolation Instrumentation (Main Steam Line Flow-High)

Reference:

Letter from P.R. Simpson (Exelon Generation Company, LLC) to U. S. NRC,

'Technical Specification Changes Related to Primary Containment Isolation Instrumentation (Main Steam Line Flow-High)," dated June 10, 2004 In the referenced letter, Exelon Generation Company, LLC (EGC) requested changes to the Technical Specifications of Facility Operating License Nos. DPR-29 and DPR-30 for Quad Cities Nuclear Power Station, Units 1 and 2. The proposed changes revise the Main Steam Line Flow-High surveillance requirements and allowable value for Primary Containment and Control Room Emergency Ventilation isolations.

In a communication from Mr. Larry Rossbach to Mr. Thomas Roddey on July 7, 2004, the NRC requested additional information regarding these proposed changes. The attachment to this letter provides the requested information. This additional information provides the set point and allowable value calculation for the proposed change.

Should you have any questions, please contact Mr. Thomas G. Roddey, at (630) 657-2811.

Respectfully, PAR Patrick R. Simpson Manager - Licensin

Attachment:

Main Steam Line High Flow Differential Pressure Setpoint Analysis, QDC-0200-1-1369 AcqA

July 19, 2004 U. S. Nuclear Regulatory Commission Page 2 cc: Regional Administrator - NRC Region IlIl NRC Senior Resident Inspector - Quad Cities Nuclear Power Station Illinois Emergency Management Agency - Division of Nuclear Safety

ATTACHMENT Main Steam Line High Flow Differential Pressure Setpoint Analysis QDC-0200-1-1 369

CC-AA-309-1001 Exelkn.. ATTACHMENT 1 Design Analysis Cover Sheet Revision 0 Nuclear ILast Page No. 33 Analysis No. QDC-0200-1-1369 Revision 0 ECIECR No. EC 345323 & EC 345324 Revision 0 & 0

Title:

Main Steam Line High Flow Differential Pressure Setpoint Analysis Station(s) Quad Cities Component(s)

Unit No.: Units 1 & 2 DPT 1(2)-0261-2A (-2B, -2C, -2D) DPT 1(2)-0261-2J (-2K, -2L. -2M)

Discipline I DPT 1(2)-0261-2E (-2F, -2G, -2H) DPT 1(2)-0261-2N (-2P, -2R, -2S)

Description 103,104/ Setpoint DPIS 1(2)0261-2A-1 (-2B-1, -2C-1, 2D-1)

Safety Class Safety Related DPIS 1(2)-0261-2E-1 (-2F-1, -2G-1, 2H-1)

System Code RX (0200) DPIS 1(2)-0261-2J-1 (-2K-1, -2L-1, -2M-1)

Structure DPIS 1(2)0261-2N-1 (-2P-1, -2R-1, -2S-1)

CONTROLLED DOCUMENT REFERENCES Document No. From/To Document No. From/To OCIS 0200-16 To QCIS 0200-64 To QCIS 0200-17 To QCIS 0200-65 To QCIS 0200-62 To QCIS 0200-66 To QCIS 0200-63 To QCIS 0200-67 To Is this Design Analysis Safeguards? Yes E No s Does this Design Analysis Contain Unverified Assumptions? Yes E No 3 ATI/AR#

Is a Supplemental Review Required? Yes E No 1 If yes, complete Attachment 3 Preparer Patricia A. Ugorcak ' f, 02-24-04 Print Name Sign Name Date Reviewer Richard H. Low _ _ _ __+ , 02-24-04 Print Name Sign Name Date Method of Review 3 Detailed Review El Alternate Calculations O Testing Review Notes: /7 Approver l. A. Khan / § - 02-24-04 Print Name Sign Name Date (For External Analyses Only) 'a-X- "'-, a*

Exelon Reviewer __S___p_____

J <7 . oN Print Name Sib NN e 6Date Approver 5 (2 PA)4A Print Name Sign Nar Date Description of Revision (list affected pages for partials):

Initial Issue in support of EC 345323 and 345234 THIS DESIGN ANALYSIS SUPERCEDES: QDC-3000-1-0986 Revision 001, after implementation of ECs 345323 &

345324

CC-AA-309 Revision 3 Page 14 of 15 ATTACHMENT I General Review Questions Page 1 of I DESIGN ANALYSIS NO. ODC- ° ; 4T- -13 9 REV: 0 f3tS En 3;3- eGc3qs3Z-Yes No N/A

1. Does the design analysis conform to design requirements? El1 El

2. Does the design analysis conform to applicable codes, standards, and regulatory requirements? El1 El

3. Have applicable design and safety limits been identified? El1 El

4. Is the analysis method appropriate? El El

5. Are the methods used and recommendations given conservative relative to the design and safety limits? rEl El El1

6. Are assumptions/Engineering Judgments explained and appropriate? El1 El

7. Have appropriately verified Computer Program and versions been El/

identified, when applicable? El1

8. Does the Computer Program conform with the NRC SER or similar 2/ El 211 document when applicable?

9. Has the input been correctly incorporated into the design analysis? El El

10. Has the input been reviewed by all cognizant design authorities? El i11

11. Are the analysis outputs and conclusions reasonable compared to the inputs and assumptions? E1 El

12. Are the recommendations/results/conclusions reasonable based on previous experience? El1 El

13. Has a verification of the design analysis been performed by alternate methods? El

14. Has all input data been used correctly and Is it traceable? E l El

15. Has the effect on plant drawings, procedures, databases, and/or plant simulator been addressed? Fi ce- Be El

16. Has the effect on other systems been addressed? ECA [Er

17. Have any changes in other controlled documents (e.g. UFSAR, Technical Specifications, COLR, etc.) been identified and tracked? . ECe. B- EO

18. When applicable, are the analysis results consistent with the proposed license amendment? a El El

19. Have other documents that have used the calculation as input been reviewed and revised as appropriate? El El

CC-AA-309 Revision 3 l Page 15 of 15 ATTACHMENT 2 Owners Acceptance Review Checklist for External Design Analysis Page I of I DESIGN ANALYSIS NO. Q0) - o0 0o - m - 13 4' REV: _

(m. 3qs3;3 *- Ec33-W Yes No N/A

1. Do assumptions have sufficient rationale? B'E lDl

2. Are assumptions compatible with the way the plant is operated and with the

2. licensing basis?

3. Do the design inputs have sufficient rationale?  : El El

4. Are design inputs correct and reasonable? 0i El El

5. Are design inputs compatible with the way the plant is operated and with the El' D a licensing basis?

6. Are Engineering Judgments clearly documented and justified? " E El 7 Are Engineering Judgments compatible with the way the plant Is operated n D El and with the licensing basis?

8. Do the results and conclusions satisfy the purpose and objective of the design [./ E El analysts?

9 Are the results and conclusions compatible with the way the plant is operated E7 E E and with the licensing basis? L

10. Does the design analysis include the applicable design basis documentation? E El 11 Have any limitations on the use of the results been identified and transmitted to the appropriate organizations? ,.E C4 E E E

12. Are there any unverified assumptions? D I El

13. Do all unverified assumptions have a tracking and closure mechanism in El El place?

EXELON REVIEWER: _______R._____________________

Print / SO

CC-AA-309-1001 Exelt n.iRevision 0 Nuclear DESIGN ANALYSIS TABLE OF CONTENTS ANALYSIS NO. QDC-0200-I-1369 REV. NO. 0 PAGE NO. 2 SECTION: PAGE NO. SUB-PAGE NO.

DESIGN ANALYSIS COVERSHEET 1 TABLE OF CONTENTS 2 1.0 PURPOSE 3 2.0 METHODOLOGY AND ACCEPTANCE CRITERIA 4 3.0 ASSUMPTIONS / ENGINEERING JUDGMENTS 6 4.0 DESIGN INPUTS 7

5.0 REFERENCES

12 6.0 CALCULATIONS 14 7.0 RESULTS AND CONCLUSION 32 ATTACHMENTS A. GE Service Information Letter No. 438, Rev. I, dated May 5, Al-A3 1994, "Main Steam High Flow Trip Setting" B BIF Vendor Information B I -B4 C. BIF Engineered Flow Applications Letter from Joseph M. Motta Cl-C3 to Jeffrey Drowley, dated July 17, 2002 D. Letter, Rosemount Nuclear Instruments, 4 April 2000, Dl-D2 Rosemount Instrument Setpoint Methodology E. Telecon, N. Archambo of Bechtel to T. Layer of Rosemount, 6- EI-E2 16-93, Rosemount Model 71ODU Trip/Calibration Unit Specifications

CC-AA-309-1001 ExeIn.M Revision 0 Nuclear Analysis No. QDC-0200-1-1369 I Revision 0 l Page 3 of 33 l 1.0 PURPOSE The purpose of this calculation is to determine Calibration Setpoints, Technical Specification Allowable Values, and Expanded Tolerances for the Unit I and 2 instrumentation that initiates closure of main steam isolation valves on high main steam line flow. Only instrument errors associated with normal operating conditions are considered. The trip signal provided by the transmitters is required in response to a Main Steam Line Break (MSLB). The location of the transmitters is projected to be a harsh environment only during the HPCI line break accident or during a LOCA. No significant beat up beyond normal conditions is expected prior to and during the time these instruments are required to function for the MSLB. This calculation addresses the specifications in GE SIL No. 438, Rev 1 (Ref 5.6).

This safety-related calculation is valid under normal operating conditions for the instruments listed below.

These instruments sense High Steam Line Flow indicative of a Main Steam Line Break and initiate a Main Steam Line Isolation when flow exceeds the trip Setpoint. These instruments also indicate differential pressure (dP) developed by the associated Main Steam Line flow venturi. However, the indication function of the instruments is not within the scope of this calculation. The instrument configuration is based on implementation of ECs 345323 and 345324 (Ref. 5.13), which install the transmitters and trip units listed below.

Venturi Flow Elements FE 1-0261-IA FE 2-026 1-IA FE 1-0261-lB FE 2-0261-1B FE 1-0261-IC FE 2-0261-IC FE 1-0261-1D FE 2-0261-ID Differential Pressure Transmitters DPT 1-0261-2A through 2H DPT 2-0261-2A through 2H DPT 1-0261-2J through 2N DPT 2-0261-2J through 2N DPT 1-0261-2P, 2R, and 2S DPT 2-0261-2P, 2R, and 2S Master Trip Units DPIS 1-0261-2A-1 through 2H-1 DPIS 2-0261-2A-1 through 2H-1 DPIS 1-0261-2J-1 through 2N-I DPIS 2-0261-2J-1 through 2N-1 DPIS 1-0261-2P-1, 2R-1, and 2S-1 DPIS 2-0261-2P-1, 2R-1, and 2S-1

CC-AA-309-1001 Exe. o n Revision 0 Nuclear I Analysis No. QDC-0200-I-1369 l Revision 0 l Page 4 of 33 l 2.0 METHODOLOGY AND ACCEPTANCE CRITERIA 2.1 Methodology 2.1.1 The methodology used for this calculation is that presented in NES-EIC-20.04, "Analysis of Instrument Channel Setpoint Error and Instrument Loop Accuracy" (Reference 5.2).

2.1.2 Because this is a Tech Spec loop, the Total Error (TE) is evaluated in conformance with a Level I Setpoint as defined in Reference 5.2, Appendix D, Graded Approach to Determination of Instrument Channel Uncertainty. As a Level 1, this means that the random errors (ca) to a I a value are combined via square-root-sum-of-the-squares (SRSS), and the non-random errors (e) are added. The total error is the sum of the random errors times two and non-random errors.

TE =2a + e 2.1.3 Clarifications to calculation methodology are as noted below.

A. Calculated values will be rounded to five decimal places for intermediate error calculation values and to three or less decimal places for final results, to match the calibration procedure values.

B. Radiation induced errors associated with normal environments are incorporated when provided by the manufacturer. If these error effects are not provided, they are considered to be small and capable of being adjusted out during calibration and are included within drift related errors.

C. For normal errors seismic events less than or equal to an OBE are considered to produce no permanent shift in the input/output relationship of a device. For seismic events greater than an OBE, it is assumed that affected instrumentation will be recalibrated as necessary prior to any subsequent accident, negating any permanent shift that may have occurred.

D. Per Appendix I of NES-EIC-20.04 (Ref. 5.2), the effects of radiation (eR), humidity (eH),

power supply (eV), calibration standard equipment (STD), and seismic (eS) under normal operating conditions may typically be considered negligible. For the evaluation of normal operating conditions, these errors are considered negligible unless otherwise noted.

E. For LOCA in the opposite unit, humidity levels outside the drywell are specified as 100%

(NC) or lower (Ref. 5.19.1). Appendix I of NES-EIC-20.04 (Ref. 5.2) recommends consideration of humidity effects only in a condensing environment. Therefore, since the environment is non-condensing in this situation, humidity effects are still considered negligible unless specified otherwise by the vendor.

With a LOCA in one unit, radiation levels in the opposite unit are considered to be X ithin the "Normal" levels for that unit. Any airborne radiation concerns, in the LOCA unit, would be controlled by that unit's emergency ventilation system and thus should not impact the opposite unit. In addition, shielding between units is considered adequate to preclude any radiation streaming concerns.

F. An Allowable Value (AV) is determined in accordance with the methodology of Reference 5.2 Appendix C, as follows.

AV=SPc+Zav Where SPc = calculated trip setpoint, and Zav is the combination of those applicable uncertainties that have been determined to affect the trip setpoint. Thus, only the

CC-AA-309-1001 Exe o n SRevision 0 Nuclear Analysis No. QDC-0200-1-1369 l Revision 0 l Page 5 of 33 l reference accuracy or repeatability (RA or RPT), calibration error (CAL), setting tolerance (ST), drift (DR) and if applicable, the input error (ain) are included.

The allowable value (AV) is determined in terms of units of the input signal to the first device in the instrument loop. A setting tolerance (ST) for the loop calibration is selected based on 1.0% of calibrated span. Although not used for the AV determination, the STs for individual loop components are selected based on 0.5% of calibrated span. This ensures that the overall loop ST is greater than any of the individual component STs. Per Reference 5.2, the STs are considered 3a values.

G. Expanded as-found tolerances (ET) are computed for the trip setpoint in accordance with the methodology of Reference 5.3, based on the applicable uncertainties Zav. The formula used to compute ET (for consistency with the Improved Technical Specification project) is:

ET = [0.7 * (AV - SPc - ST)] + ST, where AV = SPc + Zav ET = [0.7 * (Zav - ST)] + ST If the computed ET is found to be less than the ST, the ET is conservatively set equal to the ST value.

H. Temperature related errors are evaluated across the full range of ambient temperatures at which the device is used. The errors are based on the difference between the calibration temperature and the worst-case temperature at which the device is used. This methodology provides a conservative error evaluation by considering the full range of ambient temperature change specified for the applicable EQ zone. For instruments located in the reactor building, the calibration temperature is taken as the average within the normal temperature range (no LOCA in either unit) as defined in Reference 5.19.1, which is a realistic minimum calibration temperature. The instrument temperature error is evaluated from the calibration temperature to the maximum "elevated" normal temperature, which accounts for one unit's reactor building heating up due to loss of HVAC, due to a LOCA in the opposite unit. The temperature used is the maximum after the opposite unit LOCA. For instruments located in areas with a small ambient range, such as the control room or aux electric room, the temperature error is simply determined for a shift across the entire temperature range from one endpoint to the other, because in this case either extreme is a realistic calibration temperature.

I. The only temperature induced M&TE errors evaluated are those specified by the manufacturer for a specific model number, taken across the full range of non-LOCA normal temperatures. This is done because while one unit is in a LOCA, the other will be in the process of shutting down, so it assumed that no calibrations will be performed.

2.2 Acceptance Criteria There are no acceptance criteria for the setpoint or allowable value determination. The setpoint and allowable value are calculated in accordance with the methodology and the results are provided for use.

The expanded tolerances are determined as described above in Section 2.1.3.G and are acceptable if the result is greater than or equal to the applicable setting tolerance and does not result in a violation of an applicable limit.

CC-AA-309-1001 Exe nM. Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 l Page 6 of 33 3.0 ASSUMPTIONS / ENGINEERING JUDGMENTS 3.1 Published instrument vendor specifications are considered to be 2 sigma values unless specific information is available to indicate otherwise.

3.2 Evaluation of M&TE errors is based on the assumption that the test equipment listed in Section 4 is used. Use of test equipment less accurate than that listed will require evaluation of the effect on calculation results.

3.3 In accordance with Reference 5.9, it is assumed that the M&TE listed in Section 4 is calibrated to the required manufacturer's recommendations and within the manufacturer's required environmental conditions. As such, it is assumed that the calibration standard accuracy error of M&TE is negligible with respect to the other terms.

3.4 With a LOCA in one unit, the radiation levels in the opposite unit are considered to be within the "Normal" levels for that unit. Any airborne radiation concerns, in the LOCA unit, would be controlled by that unit's emergency ventilation system and thus should not impact the opposite unit. In addition, shielding between units is considered adequate to preclude any radiation streaming concerns.

3.5 As stated in Paragraph 4.17 of Reference 5.15 (ANSI/ASME PTC 6 Report- 1985), the overall uncertainty values of the flow elements in Table 4.10 of Reference 5.15 are acceptable for flow elements in service for less than or up to six months. It further states that the base uncertainty for flow elements in service for more than six months is likely to change much less with time than indicated for the initial six months. It is therefore assumed that any additional error due to damage or deposits on a flow element will be negligible with respect to the initial six-month uncertainty and will therefore not have a measurable impact on the overall loop uncertainty. Since the flow elements have been in service greater than six months, for conservatism, the largest Group 2 base uncertainty from Table 4.10 will be used to evaluate the overall flow element error.

3.6 As shown in Section 4.3.3, Reference 5.7.2 states a normal operating range of 40% to 50% relative humidity (RH) for the Rosemount Model 710DU trip system. As shown in Section 4.4.2, the location at which the trip system is installed is at 40% to 70% RH for normal operating conditions. Therefore, the normal RH of this zone exceeds the vendor's specified normal range. Per engineering judgment, it is reasonable to expect that no additional error will be induced on an electronic device such as the 710DU trip system from raising the RH from 50% to 70%. Temperature changes in this zone (the cable spreading room) are gradual, and at up to 70% RH, the RH remains low enough that condensation will not be produced.

CC-AA-309-1001 Exelnoa Revision 0 Nuclear Analysis No. QDC-0200-1-1369 Revision 0 1 Page 7 of 33 4.0 DESIGN INPUTS 4.1 Steam flow rate = 11.713 X 106 Ibm/hr. (Reference 5.10.1.)

4.2 Per Reference 5.22 (Attachment D), the stated values for Rosemount transmitter 1153 Series B Reference Accuracy, Ambient Temperature Effect, Static Pressure Effect and Power Supply Effect have a 3a confidence level.

4.3 Instrument Channel Configuration The instrument loop configuration is as designed by ECs 345323 and 345324 (Reference 5.13). It consists of a venturi flow element for each Main Steam Line that develops a differential pressure (dP) signal proportional to the square of steam flow. A transmitter senses this dP and sends an output signal to a master trip unit. When steam flow increases the dP to the setpoint, the trip unit de-energizes an auxiliary relay to initiate the PCIS Group I Isolation Logic (UFSAR Table 7.3-1, Ref.

5.10.3). There are dP loops connected across each venturi, for each of four logic channels, for a total of 16 output contacts per unit.

4.3.1 Module I Data: Venturi Flow Element wlThroat Taps EPNs: FE 1(2)-0261-IA, (-IB, -IC, -ID)

Manufacturer: BIF (Ref. 5.8)

Type: 20 inch PN A176730 Machined 304 SS (Ref. 5.8, 5.14)

Reference Accuracy: 0.5 % Flow (Ref. 5.8, 5.14)

Note: For FE 2-0261-IA, the reference accuracy was affected by damage found during Q2M20 as discussed in Reference 5.16. As specified in Reference 5.17, the reference accuracy value for FE 2-0261-4A is increased by 0.5% to 1.0 %.

4.3.2 Module 2 Data: Differential Pressure Transmitter (Ref. 5.7.1 and Design Input 4.2, except as noted otherwise).

EPN DPT 1(2)-0261-2A, through -2S, excluding -21, -20, -2Q [Ref. 5.131 Manufacturer Rosemount [Ref. 5.131 Model No. 1153DB7PA [Ref. 5.131 URL 300 psid [Ref. 5.131 Output 4-20 mA [Ref. 5.131 Reference Accuracy [3a] +/-0.25% calibrated span Drift [2ca] +/-0.2% upper range limit (URL) for 30 months Normal Temperature Range 40°F to 200°F Humidity Limits 0-100%RH (NEMA 4X)

Temperature Effect [3a] +/-(0.75% URL + 0.5% span) / 100°F Static Pressure Zero Effect [3P] +/-0.5% URIIOOO psi, correctable through re-zeroing at line pressure Static Pressure Span Effect [3a] +/-0.5% Input Reading / 1000 psi High Line Pressure Correction +1.25% of inputll000psi Overpressure Limit 2000 psig Power Supply Effect (3a) Less than 0.005% output span per volt Relative Humidity 0-100% RH Radiation Effect [2cy] +/-8.0% URL during/after exposure to 2.2 x 107 rads TID Seismic Effect [2cy1 +/-0.5% URL during/after ZPA of 4g

CC-AA-309-1 001 Exekno. Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 Page 8 of 33 4.3.3 Module 3 Data: Master Trip Unit (Ref. 5.8, 5.7.2)

EPN DPIS 1(2)-0261-2A-1 through -2S-1, excluding 1, 20-1 and 2Q-I Manufacturer Rosemount Model No. 710DUOTT23032 Input Signal 4-20 mA Output Signal Bi-stable: 24Vdc for Logic Level 1, <lVdc for Logic Level 0 Repeatability (Normal) [2a] +0.I3%(Span) (60 'F to 90 'F)

_0.20%(Span)/100 'F (Above 90 'F)

Radiation Limits None specified within limits below Seismic Effect None specified within limits below Drift Included in repeatability for up to 6 months Temperature Effect Included in repeatability Temperature Limits 60'F to 90 0 F (normal) 1607F (24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, once/year) 1850 F (Accident for 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />) 150'F (Accident for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />)

Relative Humidity 40 to 50% RH (normal) 90% for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> once/year, 90% for 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br /> (accident)

Radiation Limits <105 RADS (air) 20 year TID (Normal) 2 x 105 RADS (air) 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> TID (Accident)

Seismic Limits 1.17g OBE and 1.75g SSE Power Supply 22 to 28 Vdc Note: Repeatability specifications are applicable for a period of 6 months.

4.4 Environmental Data 4.4.1 Environmental Data for Transmitter Locations (Reference 5.8, 5.19.1, 5.10.2, 5.19.2, 5.13)

Reactor Building 1-2201-lOB, -10C 2-2202-9B, -I OB Floor Elevation 554'/ RHR IA (SE) RHR Comer 2A & 2B (NE & SE) RHR Comer Comer Rooms Room: N-19 Rooms: M-7, M-13 EQ Zones 5 5, 6 Normal Operating Conditions Ambient Temperature Range 65°F to 104°F Ambient Pressure 14.7 psia Humidity 20 to 90% RH Radiation <1.OE04 RADs (40-Yrs)

CC-AA-309-1001 Exelonm SRevision 0 Nuclear Analysis No. QDC-0200-I-1369 l Revision 0 l Page 9 of 33 4.4.2 Environmental Data for Trip Unit Location Trip Unit Locations: (Reference 5.8, 5.19.1, 5.13)

Service Building 1-2201-73A, B, AA, BB 2-2202-73A, B, AA, BB Floor Elevation 609' l Cable G-26 F-26 Spreading Room EQ Zone 18a Normal Operating Conditions Ambient Temperature Range 70'F to 80F Ambient Pressure 14.7 psia Humidity 40 to 70% RH Radiation <I.OE04 RADs (40-Yrs) 4.5 Calibration Data (for analog trip system installed by EC 345323 and 345324)

Per ECs 345323 and 345324, the operating input range (calibrated span) for the transmitters is 0-300 psid for a 4-20 mA output.

ECs 345323 and 345324 will revise the calibration procedure(s) to calibrate the main steam high flow dP instrument loops in the same way as the other existing analog trip instrument loops are calibrated.

Specifically, for the loop calibration, first the transmitter calibration is done with pressure input read on certified pressure M&TE, while reading mA output at the transmitter and Vdc input to the MTU on certified DMMs. Then the trip point actuation will be observed in response to increasing pressure input, with a setting tolerance in input pressure units. Per 2.1.3.F, as established by ECs 345323 and 345324, the setting tolerance is +/-3.0 psid (1.0% of span) for the string calibration of the trip point. For the transmitter calibration, per 2.1.3.F, the setting tolerance is established as 40.08 mA (0.5% of span).

For the MTU calibration check, the stable input current is applied and read at the trip unit on the Rosemount readout assembly and calibration unit installed in the instrument nests in panels 2201(2)-

73A (B, AA, BB). Current is increased until the trip unit actuates. Per 2.1.3.F, as established by ECs 345323 and 345324, the setting tolerance is +0.08 mA (0.5% of span) for the calibration of the trip unit alone.

Per Reference 5.11, typical surveillance intervals and late factors for the transmitter/trip unit instrument loops are as follows:

Calibration Frequency: Transmitter through trip unit loop calibration: 24 months Trip Unit Alone: 92 days Late Factor 25 % Nominal Frequency (Ref. 5.1 1)

Reference 5.11 will be revised to include these values for the MSL High Flow Isolation Signal.

4.6 Calibration Instrument Data - Calculation NED-I-EIC-0255, Measurement and Test Equipment (M&TE) Accuracy Calculation For Use With ComEd BWR(s), Rev. 0, Reference 5.9 (pages 66 and 86), is used to provide the errors for the calibration instruments noted herein. Since ECs 345323 and 345324 will replace the MSL High Flow switches with transmitters and trip units, the calibration procedures must be revised to include the test equipment listed here. The list provides the errors for these instruments from the above noted calculation. The list also provides the evaluation parameters used in NED-I-EIC-0255.

CC-AA-309-1001 Exelon. Revision 0 Nuclear r Analysis No. QDC-0200-I-1369 I Revision 0 Page 10 of 33 4.6.1 Pressure Sensing M&TE, for transmitter input Calibration Instrument MTE Error (Ia) Evaluation Parameters MTE2 - Heise CMM (0 -400 psig) + 1.744484 psig 104 OF MTE3 - Druck DPI 601 (0 - 500 psig) + 0.730068 psig 104 OF Note: MTE error values for the Druck DPI-601 could be reduced slightly by using the actual calibration limit for reading value. For convenience, the error values were simply transposed from Reference 5.9, as the impact on the total instrument loop error is insignificant.

4.6.2 Rosemount Calibration Unit and Readout Assembly (Ref. 5.7.2)

Stable Calibration Current Range: 3.5 to 20.5 mA Stability: + 5 ItA (2c per Section 3.1)

Readout Assembly Resolution: :0.01 mA over normal temperature range of 40'F to 104'F, (2c per Section 3.1).

Per Reference 5.23, errors associated with the calibration unit are included in the trip unit repeatability. Therefore, no additional calibration error is required for the MTU.

4.7 From Reference 5.11 the maximum limit for Reactor pressure at the steam dome is 1005 psig (- 1020 psia). For dry saturated steam at this pressure, the temperature is 546.99 'F (Reference 5.12, page A-15).

4.8 The isentropic exponent for an ideal gas is the ratio of specific heats of fluid. For dry saturated steam at 1050 psia and 550 'F the value is approximately 1.255 (Reference 5.6). According to Reference 5.12, page A-9, the value is approximately 1.257 for dry saturated steam at 1000 psia. Therefore, the isentropic exponent for dry saturated steam at 1020 psia is between these values and is approximately 1.256.

4.9 Coefficient of discharge for a venturi tube with a machined entrance cone, C = 0.995 (Ref. 5.6 p3).

Per Reference 5.12 page A-20, this value is approximately constant for fully turbulent flow.

4.10 Venturi throat inside diameter, d = 9.97 in (Reference 5.14).

4.11 Pipe inside diameter (20", sch 80 - Reference 5.8), D = 17.938 in (Reference 5.12 page B-18).

4.12 Area thermal expansion factor, F. = 1.0092 (Reference 5.6).

4.13 Upstream specific volume (ft3/Abm) at 1020 psia and 546.99 'F, v = 0.4362 ft3/lbm (dry, saturated steam - ASME Steam Tables - 1967).

4.14 The flow element is a BIF venturi according to Reference 5.8. The accuracy of BIF venturi tubes is

+/-0.5% flow according to vendor information. (Reference 5.18, Attachment B) 4.15 The Licensed Power Uprate (LPU) Rated Steam Flow is 11.713 Mlb/hr (Ref.5.10.1). Dividing this across the four main steam lines, 100% power flow in each steam line is (11.713 Mlblhr)* (1000 klb/Mlb)/4 = 2928.25 klb/hr.

4.16 The Analytical Limit (AL) for this function is 140% of LPU Rated Steam Flow (Ref. 5.10.3). Based on four main steam lines, the AL per steam line is:

AL (per steam line) = 140% (2928.25 klb/hr) = 4099.55 klb/hr

CC-AA-309-1001 exelon6 m SRevision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 l Page 11 of 33 4.17 From Reference 5.15 (ASME PTC 6), the steam flow element accuracy error presented is valid only if the ratio of the dP to the inlet pressure is <0.10. The dP and inlet pressure at 100% flow are utilized to calculate the pressure ratio. Using Reference 5.6, dP at 100% flow (2928.25 klb/hr per venturi) is 111.06 psid (as calculated in Section 6.0 of this calculation). The maximum inlet pressure at 100%

flow is 1020 psia and the density (rho) is 2.293 (lb/ft 3 ). The ratio of dP to inlet pressure is:

Units I & 2: Press. Ratio@100% PWR = 111.06 psi / 1020 psia = 0.109 Although the ratio slightly exceeds 0.10, the uncertainties from ASME PTC 6 (Reference 5.15) are considered a reasonable approximation of the flow element uncertainties.

4.18 As stated in Foreword to ANSI/ASME PTC 6 Report - 1985 (Ref. 5.15), the possible errors associated with steam turbine testing are expressed as uncertainty intervals which, when incorporated into this model, will yield an overall uncertainty for the test result which provides 95% coverage of the true value. Therefore, the overall uncertainty of the flow section is taken to represent a 2cT value.

4.19 For the purpose of this calculation, ambient environmental conditions (pressure, temperature, or humidity) in the zone of the process pipe will have no effect on the flow element in comparison to the effects of the process flow itself, because the flow element is a steel nozzle inside the 20" process line.

The ambient pressure and humidity clearly can have no effect on the nozzle inside the process line, and the nozzle will be at the temperature of the process. No ambient zone effects for the nozzle location will be applied to the nozzle.

CC-AA-309-1001 Exeo 16 Revision 0 Nuclear Analysis No. QDC-0200-I-1369 l Revision 0 lT Page 12 of 33 l

5.0 REFERENCES

5.1 ANSI/ISA-S67.04-1994, "Setpoints for Nuclear Safety Related Instrumentation" 5.2 "Analysis of Instrument Channel Setpoint Error and Instrument Loop Accuracy," NES-EIC-20.04, Revision 3, October 23, 2000 5.3 "Instrument Performance Trending," CornEd procedure ER-AA-520 Revision 3, 9-6-2002 5.4 Quad Cities Unit I Instrument Surveillance Procedures:

5.4.1 QCIS 0200-16, Rev. 7, Unit 1 Division I Main Steam Line High Flow Indicator and Switch Calibration and Functional Test 5.4.2 QCIS 0200-17, Rev. 7, Unit I Division I Main Steam Line High Flow Switch Calibration and Functional Test 5.4.3 QCIS 0200-62, Rev. 1, Unit 1 Division H Main Steam Line High Flow Indicator and Switch Calibration and Functional Test 5.4.4 QCIS 0200-65, Rev. 2, Unit I Division II Main Steam Line High Flow Switch Calibration and Functional Test 5.5 Quad Cities Unit 2 Instrument Surveillance Procedures:

5.5.1 QCIS 0200-63, Rev. 0, Unit 2 Division I Main Steam Line High Flow Indicator and Switch Calibration and Functional Test 5.5.2 QCIS 0200-64, Rev. 0, Unit 2 Division II Main Steam Line High Flow Indicator and Switch Calibration and Functional Test 5.5.3 QCIS 0200-66, Rev. 1, Unit 2 Division I Main Steam Line High Flow Switch Calibration and Functional Test 5.5.4 QCIS 0200-67, Rev. 1, Unit 2 Division II Main Steam Line High Flow Switch Calibration and Functional Test 5.6 General Electric Service Information Letter (SIL) No. 438, Rev.1, dated May 5, 1994, regarding "Main Steam Line High Flow Trip Setting" (Attachment A) 5.7 VTIP Binder C0066 Volumes I and 2 5.7.1 VTIP Manual R369-0299, Rosemount Product Manual for Alphaline Transmitters 1153 Series B, Manual 4302, dated May 1999 (In VTIP Binder C0066 Volume 1) 5.7.2 VTIP Manual R369-0035, Rosemount Model 710DU Operations Manual, 4471-1, dated April 1983 (In VTIP Binder C0066 Volume 2) 5.8 Quad Cities PassPort Component Data Sheets for the following components:

DPT 1(2)-0261-2A through 2S (excluding -2I, -20, -2Q), as revised per ECs 345323 Rev. 0 and 345324 Rev. 0 DPIS I(2)-0261-2A-1 through 2S (excluding 1, 1, -2Q-1), as revised per ECs 345323 Rev. 0 and 345324 Rev. 0)

FE 1-0261-lA thru ID, FE 2-0261-ID (Rev 001)

FE 2-0261-IA thru IC (Rev 000) 5.9 Calculation NED-I-EIC-0255, Rev. 0, "Measurement and Test Equipment (M&TE) Accuracy Calculation for Use With Commonwealth Edison Company Boiling Water Reactors", dated 4/14/94

CC-AA-309-1001 Exe o M Revision 0 Nuclear Analysis No. QDC-0200-I-1369 l Revision 0 l Page 13 of 33 l 5.10 Quad Cities UFSAR, Rev. 7, January 2003 5.10.1 Table 4.1-3, Thermal and Hydraulic Design Data 5.10.2 Section 9.4.7, Reactor Building Ventilation System 5.10.3 Table 7.3-1, Analytical Limits for Group Isolation Signals 5.11 Quad Cities Technical Specifications, Amendments 218 and 212 5.12 Crane Technical Paper No.410, 25th Printing, 1991 5.13 EC 345323 Rev. 0 and EC 345324 Rev. 0, Main Steam Line High Flow Switch Replacement 5.14 "20IN 17.938 x 9.974 Venturi Insert Nozzle" Vendor Drawing (BIF General Signal Corporation), A-176730 Rev. 1, dated 1/13/69 5.15 ANSI/ASME PTC 6 Report, "Guidance for Evaluation of Measurement Uncertainty in Performance Tests of Steam Turbines", Sections 4.15 - 4.18, 1985 5.16 EC 338015, Revision 0, Evaluation of Main Steam Line 'A' Flow Restrictor Damage 5.17 BIF Engineered Flow Applications Letter from Joseph M. Motta to Jeffrey Drowley (Exelon), dated July 17, 2002 (Attachment C) 5.18 BIF Vendor Information (Attachment B) 5.19 Quad Cities Drawings:

5.19.1 Environmental Zone Maps, M-4A Series Sh. 1, Rev. E, Basement Floor Plan Figure 1 Sh. 2, Rev. F, Ground Floor Plan, El. 595'-0", Figure 2 Sh. 6, Rev. A, Notes and References 5.19.2 Quad Cities Drawing M-6, Rev. C, General Arrangement Basement Floor Plan Units I & 2 5.20 Quad Cities Drawings, as revised for EC 345323 5.20.1 CID-13 Sh. 1, Control and Instrumentation Main Steam System - Quad Cities Station Unit I 5.20.2 M-13 Sh. 1,DiagramofMainSteamPiping 5.20.3 4E-1503A, Schematic Diagram PCIS Panel 901-15 Trip Logic & Condenser 5.20.4 4E-1503B, Schematic Diagram PCI System Panel 901-17 Trip Logic 5.21 Quad Cities Drawings, as revised for EC 345324 5.21.1 CID-60 Sh. 1, Control and Instrumentation Main Steam System - Quad Cities Station Unit 2 5.21.2 M-60 Sh. 1, Diagram of Main Steam Piping 5.21.3 4E-2503A Sh. 1, Schematic Diagram PCIS Panel 902-15 Trip Logic & Condenser 5.21.4 4E-2503A Sh. 2, Schematic Diagram PCIS Panel 902-15 Trip Logic & Condenser 5.21.5 4E-2503B Sh. 1, Schematic Diagram PCIS Panel 902-17 Trip Logic & Condenser 5.21.6 4E-2503B Sh. 2, Schematic Diagram PCIS Panel 902-17 Trip Logic 5.22 Letter, Rosemount Nuclear Instruments, 4 April 2000, Rosemount Instrument Setpoint Methodology (Attachment D) 5.23 Telecon, N. Archambo of Bechtel to T. Layer of Rosemount, 6-16-93, Rosemount Model 71 ODU Trip/Calibration Unit Specifications (Attachment E)

CC-AA-309-1001 Exebn.. SRevision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 Page 14 of 33 6.0 CALCULATIONS Using Reference 5.6, (GE SIL 438, Rev. 1) the operating differential pressures developed across each of the four main steam venturi are determined. The differential pressures for 100% power (per Design Input 4.15, 2928.25 klb/hr per venturi) and 140% power (per Design Input 4.16,4099.55 klb/hr per venturi) are calculated as follows.

From Attachment to GE SIL 438, Rev. 1:

W= 1890.07*(CYd'F.)*[(pAP)/(l - p 4 )]) Eq. 1 Where: W = mass steam flow in lb/hr C = discharge coefficient = 0.995 Y = gas expansion factor (ratio)

Y = {r2 1k(k/(k-l))[(l _rl-l'k)/(I-r)][(-fp4 )/(1-f3 4r21 )]) /' Eq. 2 And: T = ratio: throat StatPres to inlet StatPres (psia) = (Pi - AP)/PI k = ratio of specific heats, or isentropic exponent, dry saturated steam = 1.256 for pressure of 1020 psia d = throat diameter Units I and 2: 9.970" Fa = area thermal expansion factor = 1.0092 p = density of upstream fluid (1/v = I / 0.4362 @ 1020 psia = 2.293)

AP = differential pressure (psid) p = ratio of throat to pipe diameters Units I and 2: (9.970"/17.938")

Solving for AP: AP = EW/(1890.07*CYd 2 F.)j?[(14V)Ypj Eq. 3 Initial value at Y=1: AP = [W/(1890.07*Cd 2 F3 )]2 [(1IBp4 )/p] Eq. 4

CC-AA-309-1001 Exelkn.. Revision 0 Nuclear l Analysis No. QDC-0200-1-1369 l Revision 0 1 Page 15 of 33 Starting with Equation 4 and then using Equations 3 and 2, the following tables successively iterate the differential pressures at 100% and 140% (AL) flow values, until the value stops changing. The values determined are operating differential pressures at the corresponding system static pressure as shown for each flow. In these iterations, all calculated values are rounded to 5 decimal places, and then the final dP is rounded to 2 places.

Operating dPs C I I 1k ID lF 1_ _ ]kI(k-1) 2/k 0.995 1 11.256 19.97 11.0092 10.555803 14.906250 .592357 W Static P _ AP)y=l rl YI API Nr2 Y2 AP2 2928250 1020 2.293 95.04243 0.90682 0.93599 108.48635 0.89364 0.92684 110.63893 4099550 1020 2.293 186.28316 0.81737 0.87327 244.27359 0.76052 0.83255 268.75276 r3 Y3 AP3 r4 Y4 __ _

2928250 1020 2.293 0.89153 0.92537 110.99072 0.89119 0.92513 111.04832 4099550 1020 2.293 0.73652 0.81513 280.36244 0.72513 0.80680 286.18167

_ r5 YS AP5 Ir6 Y6 AP6 2928250 1020 2.293 0.89113 0.92509 111.05792 j0.89112 0.92509 111.05792 409955011020 t2.293 0.71943 0.80262 _289.17027 10.71650 10.80047 7290.72573

__r7 Y7 AP7 r8 Y8 AP8 2928250 1020 2.293 0.89112 0.92509 111.05792 0.89112 0.92509 111.05792 = 111.06 4099550 1020 2.293 0.71497 0.79935 291.54099 0.71418 0.79876 291.97184

_ r9 Y9 AP9 rlO Y10 APIO 4099550 1020 2.293 0.71375 0.79845 292.19861 0.71353 0.79829 292.31575 rl Y11 API I r12 Y12 AP12 4099550 1020 2.293 0.71342 0.79821 292.37434 0.71336 0.79816 292.41098 _ _

.r3 Y13 AP13 rl 4 Y14 AP14 4099550 1020 2.293 0.71332 0.79813 292.43296 0.71330 0.79812 292.44029 rlS Y15 APIS rl6 Y16 AP16 4099550 1020 2.293 0.71329 0.79811 292.44762 0.71329 0.79811 292.44762 ___

_r17 Y17 AP17 rl8 Y18 AP18 _

4099550 1020 2.293 0.71329 0.79811 292.44762 - 292.45 From the table above, the differential pressure at 100% flow (2928.25 klb/hr) is 111.06 psid, and at the AL of 140% flow (4099.55 klb/hr) is 292.45 psid.

CC-AA-309-1 001 Exe o n >Revision 0 Nuclear I Analysis No. QDC-0200-I-1369 l Revision 0 l Page 16 of 33 l 6.1 FLOW ELEMENT ERRORS - Module I Classification of Module Per Section 4.3.1, Module I is a venturi, with steam flowing through it developing differential pressure at the process taps. Therefore, it is classified as an analog module.

6.1.1 Random Error (cr1 )

6.1.1.1 Venturi Uncertainty (UO)

The error associated with the venturi is calculated per the methodology contained in Reference 5.15, using the largest Group 2 base uncertainty value per Assumption 3.5, for a flow nozzle with throat tap without upstream flow straighteners. Per the general note in Table 4.10 of Reference 5.15, the following formula applies:

UO = (UB + ULNS + UP2 + UDSL )25 Base Uncertainty (Un}

The base uncertainty UB is taken from Table 4. 10 of Reference 5.15, Item H, for steam flow through a nozzle with throat tap in an uncalibrated section, without upstream flow straighteners:

UB= 3.0% flow Note: The base accuracy of 3% flow is conservative and bounds the vendor reference accuracy of +/- 1.0% for FE 2-0261 -1A and +/- 0.5% for the other FEs as defined in Section 4.3 for Module 1.

Minimum Upstream Straight Run Uncertainty (Up Per Sections 4.10 & 4.11, the inner pipe diameter is 17.938" and the nozzle throat diameter is 9.970". This produces a beta ratio P3 = 9.970/17.938 = 0.556. Conservatively approximating with an upstream straight pipe run ratio of I for a 0.5 ,Bratio curve in Figure 4.5 of Reference 5.15, means that ULNs = 1.25% of flow.

Therefore: ULNs = 1.25% flow Beta Ratio Uncertainty (UE)

From Figure 4.6 of Reference 5.15 the beta ratio effect for an uncalibrated flow element with a beta ratio of up to 0.56 is:

Up = 0.18% of flow Minimum Downstream Straight Run Uncertainty (Urs)

Per Sections 4.10 & 4.11, the inner pipe diameter is 17.938" and the nozzle throat diameter is 9.970". This produces a beta ratio ,B= 9.970"/17.938" = 0.556. Conservatively approximating with a downstream straight pipe run ratio of 0.8 for up to a 0.75 j3 ratio curve in Figure 4.9 of Reference 5.15, means that ULNs = 1.05% of flow.

Therefore: ULNs = 1.05% flow

CC-AA-309-1 001 Exekm.. nRevision 0 Nuclear Analysis No. QDC-0200-I-1369 I Revision 0 l Page 17 of 33 l Nozzle Overall Uncertainty (UO)

As stated in the beginning of this section, the overall flow element uncertainty is then calculated as: (which is taken as a 2a value per Design Input 4.18)

UO =(UB 2

+ UN 2 + U02 + UDSL2 )0 .5 = ((3.0)2 + (1.25)2 + (0.18)2 + (1.05)2)05

+/- 3.42 % of flow [2a]

6.1.1.2 Nozzle Reference Accuracy (RAI)

The overall uncertainty is stated in terms of % of flow. This will be converted into terms of klb/hr and then psid, and used as the reference accuracy. The reference accuracy will be determined for the flow value corresponding to the AL value 140% of flow, because this will always be larger than the actual instrument setpoint value.

From Section 6.1.1.1, UO = +3.42 % of flow [2c0]

At 4099.55 klb/hr (140% flow), and dividing by 2 to get a Ia value:

U0140 = 3.42 % * (4099.55 klbfhr)12 = +/- 70.102 klbfhr [lI]

The differential pressure must be determined for flows of 4099.55 470.102 klb/hr, which equals 4029.448 klb/hr and 4169.652 klb/hr.

dP determination Equations 1, 2, 3 and 4 below are taken from Reference 5.6, GE SWL 438, Revision 1.

From Attachment to GE SIL 438, Rev. 1: W = 1890.07*(CYd2 Fa)*[(pAP)/(1 - 134)V" Eq. 1 Where: W = mass steam flow in lb/hr C = discharge coefficient = 0.995 Y = gas expansion factor (ratio)

Y = {r'&(kI(k-1))[(1 rl"'\)/(1-r)][(1 -p4)/(1-B4r21)]} / Eq. 2 And: r = ratio: throat StatPres to inlet StatPres (psia) = (Pi - AP)/Pi k ratio of specific heats, or isentropic exponent, dry saturated steam = 1.256 for a pressure of 1020 psia d = throat diameter Units 1 and 2: 9.970" Fa = area thermal expansion factor = 1.0092 p = density of upstream fluid (1/v = 1 / 0.4362 @ 1020 psia = 2.293)

AP = differential pressure (psid)

P = ratio of throat to pipe diameters Units I and 2: (9.970"/1 7.93 8")

Solving for AP: AP = [W/(1890.07*CYd 2 Fa)]2 [(1-,p 4 )/p] Eq. 3 Initial value at Y=: AP = [W/(1890.07*Cd 2 Fa)] 2 [(1-p 4 )fp] Eq. 4 Starting with Equation 4 and then using Equations 3 and 2, the following table successively iterates the differential pressures for desired flow values, until the value stops changing. The values determined are operating differential pressures at the corresponding system static pressure as shown for each flow.

In these iterations, all calculated values are rounded to 5 decimal places, and then the final dP is rounded to 2 places.

CC-AA-309-l 001 ExekIrn.S Revision 0 Nuclear I Analysis No. QDC-0200-I-1369 I Revision 0 Page 18 of 33 Units 1 & 2 Operating dPs C IKI D F k/(k-1) 2/k 0.995 1.256 9.970 1.0092 0.555803 4.906250 1.592357 W Static P P AP@Y=1 Rl API r2 Y2 AP2 4029448 1020 12.293 179.96677 0.82356 0.87766 233.63597 0.77095 0.84008 255.00637 4169652 1020 2.293 192.70848 0.81107 0.86879 255.31199 0.74969 0.82471 283.33375

_ r3 Y3 AP3 r4 Y4 AP4 4029448 1020 2.293 0.74999 0.82492 264.46528 0.74072 0.81819 268.83387 _

4169652 1020 f2.293 10.72222 0.80467 297.62213 0.70821 0.79437 305.39025

___ Jr5 I Yr APS lr6 lY6 IAP6 I 4029448 1020 2.293 10.73644 10.81507 1270.89595 0.73442 0.81359 1271.88242 I 4169652 1020 12.293 10.70060 10.78875 1309.75769 0.69632 10.78558 1312.26262 1 Ilr7 lY7 IAP7 lr8 lY8 jAP8 J 4029448 11020 2.293 10.73345 0.81289 1272.35087 10.73299 10.81255 1272.57884 J _

416965211020 12.293 10.69386 10.78376 1313.71454 10.69244 10.78270 1314.56483 1 I 1 Ir9 IY9 IAP9 irlO YO lAPIO 4029448 j1020 12.293 10.73277 j0.81239 1272.68622 0.73266 0.81231 272.73993 4169652 10-20 12.293 10.69160 0.78208 1315.06378 10.69111 10.78172 1315.35403 =

I

____ r~i JYii lAPI1 r12 Y12 AP12______

4029448 11020 12.293 10.73261 10.81227 1272.76679 10.73258 10.81225 5272.78023 4169652 11020 12.293 10.69083 10.78151 1315.52353 10.69066 0.78138 315.62853 ii Irl3 JY13 jAP13 jr14 Y14 APM4 02944811020 12.293 10.73257 10.81224 1272.78694 10.73256 0.81224 272.78694 416965211020 12.293 10.69056 10.78131 1315.68509 10.69050 50.78126 5315.72550 iY5 I IrS IYIS API5 irl6 Y16 AP16 _

4029448 11020 12.293 10.73256 10.81224 1272.78694 1 5 5 1= 272.79 4169652 11020 (2.293 10.69047 j0.78124 (315.74166 j0.69045 (0.78123 (315.74975 _

lrl7 lY17 IAP17 Ir18 lYI8 IAP18 1 4169652 1020 2.293 0.69044 0.78122 315.75783 0.69043 0.78121 315.76591 I I---!  ! r19 5Y19 5AP19 1r20 5Y2o IAP20  ! -  !

416965211020 12.293 10.69043 10.78121 1315.76591 50.69043 1315.76591 1=0.78121 315.77 From Section 6.0, the differential pressure at 140% flow (4099.55 klb/hr) is 292.45 psid. Therefore the flow element error in terms of psid is:

At -3.42% flow: FEL = 272.79 psid - 292.45 psid = -19.66 psid At +3.42% flow: FE1I = 315.77 psid - 292.45 psid = 23.32 psid The greater in magnitude of these is conservatively applied in both directions as the flow element reference accuracy.

RAI =i: 23.32 psid [Ia]

CC-AA-309-1001 Exelnm. Revision 0 Nuclear

[ Analysis No. QDC-0200-I-1369 Revision 0 l Page 19 of 33 l 6.1.1.3 Calibration Error and Setting Tolerance (CALI & STI)

The flow element is a passive mechanical device that is not field calibrated. Therefore, CALI = 0 and STI =0 6.1.1.4 Drift (oDI)

The flow element is a passive mechanical device that does not drift. Therefore, cDi =0 6.1.1.5 Random Input Errors (crl Nn)

The nozzle is the first element in each loop and therefore has no random input errors.

Therefore, cIj:n = [lo]

6.1.1.6 Determination of Total Random Errors (Eal)

Bal = [RAt 2 + CAL12 + STI2 + crD12 + slIn2105 Because all these values are zero except for RAI, this simplifies to: Zal = RAI at 140% flow: Sol = RA1 = +/- 23.32 psid [Io]

CC-AA-309-1001 exe 6 n. Revision 0 Nuclear I Analysis No. QDC-0200-I-1369 l Revision 0 l Page 20 of 33 l 6.1.2 Non-Random Errors (Eel)

The nozzle is a passive mechanical device, a piece of steel welded inside of a pipe section. The differential pressure monitored at the taps is proportional to the square of the flow through the nozzle.

As such it is not affected by the following non-random errors:

Ambient Humidity Errors: elH = 0; Per Design Input 4.19, no ambient effects inside the pipe.

Ambient Temperature Errors: FIT = 0; per Design Input 4.19, no ambient effects inside the pipe.

Radiation Errors: OR = 0; radiation will not affect the dP developed by the nozzle.

Seismic Errors: elS = 0; seismic event will not alter the nozzle.

Static Pressure Effects: el SP = 0; changes in static pressure are accounted for in the process error.

Ambient Pressure Errors: elP = 0; per Design Input 4.19, no ambient effects inside the pipe.

Power Supply Effects: elV =0; no power supply 6.1.2.1 Process Error (elp)

The differential pressure at the taps of the venturi flow element for a given mass flow rate varies with the upstream steam line pressure primarily due to variation in saturated steam density with pressure. The differential pressure varies to a lesser extent with changes in expansion factor. However, the equations of flow in Section 6.0 show the process effect is inversely proportional with steam line pressure so that decreasing pressure (decreasing density) results in a conservatively higher DP for a given mass flow rate. Fluctuation in operating pressure during full power operation is restricted to below the nominal Reactor Steam Dome pressure in accordance with specification 3.4.10 of Reference 5.11. Therefore, the random effect on differential pressure that can contribute a non-conservative error is zero and the random process error is established as, elp=O 6.1.2.2 Non-Random Input Errors (el N)

The nozzle is the first element in the loop and so has no non-random input errors, therefore:

elin= 0 6.1.2.3 Total Non-Random Error (Eel)

In accordance with Section 2.1.2, the bias errors from Section 6.1.2 through 6.1.2.2 are added.

Therefore, Eel = +[elH+elT+elR+elelSlSP+elP+eIV+elp+eldN]

Because all of these errors are zero, Ec1 = 0

CC-AA-309-1001 Exe len okRevision 0 Nudear I Analysis No. QDC-0200-1-1369 I Revision 0 1 Page 21 of 33 6.2 DIFFERENTIAL PRESSURE TRANSMITTER ERRORS - Module 2 Classification of Module Module 2 is a differential pressure transmitter that senses the differential pressure across the main steam venturi and produces an analog signal proportional to differential pressure that is sent to the master trip unit. It has an analog input operating range of 0-300 psid (Input 4.5), and an analog output range of 4-20 mA (Input 4.3.2). Therefore, it is classified as an analog module.

6.2.1 Transmitter Random Errors (o2) 6.2.1.1 Transmitter Reference Accuracy (RA2)

By direct application of the vendor's specifications listed in Section 4.3.2:

RA2 = +/-0.25% * (Span) [3a]

= +/-0.25% * (16 mA)/3 = + 0.01333 mA [la]

6.2.1.2 Transmitter Calibration Error (CAL2)

Per Section 4.5, the transmitter is calibrated in a string with the trip unit by applying pressures of known accuracy to the input and adjusting the devices for proper output. Therefore the transmitters contribution to the calibration error is based only on the error of the MTE used to measure the transmitter input pressure, and consists of the following random components:

• the inaccuracy of the calibration standards used to calibrate the measurement and test equipment (STD2)

• the inaccuracy of the pressure gauge used to measure the transmitter input pressure during calibration (MTE2)

These quantities will be calculated and combined by the SRSS method.

6.2.1.2.1 Calculation of STD2 Per Section 3.3, the calibration standard accuracy error of the measurement and test equipment is negligible as noted below:

STD2 =0 6.2.1.2.2 Calculation of MTE2 MTE2 is defined as the error induced on the transmitter as a result of the inaccuracy of the pressure gauge used to measure the input signal to the device during calibration. For conservatism, the pressure gauge with the worst accuracy is used in this error determination.

From the M&TE accuracy data listed in Section 4.6.1:

MTE2 = 1.74448 psid [la]

This is converted to mA by multiplying by the ratio of the transmitter input to output spans (CFEo). Per 4.5, the transmitter will be calibrated to operate at 0-300 psid input for a 4-20 mA output.

MTE2' = CFEo

• MTE2 = (16 mAI300 psid) * (41.74448 psid) = 40.09304 mA [1a]

6.2.1.2.3 Total Calibration Error (CAL2)

The total calibration error associated with the transmitter is:

CAL2 = 1[(STD2) 2 + (MTE2) 21]' = +/-[(0)2 + (0.09304 mA)2 ]/'=+ 0.09304 mA [la]

CC-AA-309-1001 Exe n~MRevision 0 Nudear Analysis No. QDC-0200-I-1369 Revision 0 Page 22 of 33 6.2.1.3 Transmitter Setting Tolerance (ST2)

From Section 4.5 and 2.1.3.F, the setting tolerance for the string calibration to the MTU is

+3.0 psid, taken as a 3a value. This is converted to mA by multiplying by the ratio of the spans, as in Step 6.2.1.2.2, and taken to a Ia value by dividing by 3:

ST2 = (+/-3.0 psid)*CFEO / 3 = (+/-3.0 psid)*(l 6 mA /300 psid) / 3 = 0.05333 mA[la]

6.2.1.4 Drift Error (DR2)

From the vendor's specifications listed in Section 4.3.2, the drift error for the transmitter is given below. Per Input 4.5, the surveillance interval (SD) for the device is 24 months with an additional 25% late factor. Therefore, the expected drift error converted to Ia is:

DR2 =+/-(0.2%(URL)!30 months)(SI)(1.25) [2a]

= +(0.2%(300 psid)/30 months)(24 months)(1.25) /2 = +0.30000 psid [ICY]

This is converted to mA by multiplying by the ratio of the spans, as in Step 6.2.1.2.2:

DR2' = DR2*(16 mA/300 psid) = (+/-0.30000 psid)*(16 mA] 300psid)

= +/-0.01600 mA [la]

6.2.1.5 Temperature Error (e2M)

From Section 4.4.1, the ambient temperature of the transmitter environment during normal operating conditions, varies from a minimum of 65 'F to a maximum of 104 'F. From the vendor's specifications listed in Section 4.3.2, the error induced on the transmitter as a result of this temperature variation converted to Ia is:

e2T = +((0.75%(URL) + 0.5%(Span))11 00 'F)( AT) [3a]

= +/-((0.75%(300 psid) + 0.5%(300 psid))!100 0F)(104 IF -65 IF) / 3

= +0.48750 psid [la]

This is converted to mA by multiplying by the ratio of the spans, as in Step 6.2.1.2.2:

e2T' = e2T*(16 mAI300 psid) = (+/-0.48750 psid)*(l6 mAI300 psid)

= +0.02600 mA [laY]

6.2.1.6 Static Pressure Error (elSP)

From Section 4.3.2, the error induced on the transmitter due to the system static pressure is composed of a zero effect and a span effect. These two values will be determined and combined algebraically. From Section 4.7, the static pressure is 1005 psig.

6.2.1.6.1 Zero Effect The static pressure zero effect is defined as the error induced on the instrument zero when the device is zeroed at atmospheric pressure but operated at line pressure. This error is given by:

ZE = (+/-0.5%(URL)/l000 psi)*(Static Pressure)

= (+/-0.5%(300 psid)/1000 psi)*(l005 psi)

= +1.50750 psid [3a]

CC-AA-309-1001 Exebam Revision 0 Nudear I Analysis No. QDC-0200-I-1369 Revision 0 l Page 23 of 33 l 6.2.1.6.2 Span Effect The static pressure span effect is defined as the uncertainty associated with the correction factor used to compensate for the shift in output span due to the system static pressure. The upper calibration limit is used in this error determination as this will produce the most conservative error analysis result. From Section 4.3.2, the uncertainty is given by:

SE = (+0.5%(Reading)/ 1000 psi) *(Static Pressure)

= (+/-0.5%(300 psid)l1000 psi)*(l005 psi)

= +1.50750 psid [3a]

6.2.1.6.3 Total Static Pressure Error (e2SP)

For conservatism, the total error induced on the transmitter as a result of the system static pressure is calculated by algebraically combining the zero and span effects as determined below:

e2SP = +[ZE + SE] = 4[1.50750 psid + 1.50750 psid]

= -3.01500 psid [3cy]

This is converted to mA by multiplying by the ratio of the spans, as in Step 6.2.1.2.2, and taken at a Ia value:

e2SP' = (e2SP)*(16 mA/300 psid)/3 =(3.015 psid / 3)*(16 mA/300 psid)

= 0.05360 mA [Icy]

6.2.1.7 Power Supply Error (e2V)

Per Section 4.3.2, the vendor specifies a power supply effect of <0.005% span per volt. This effect is considered negligible with respect to other errors per Section 2.1.3.D.

e2V =O mA [Ic]

6.2.1.8 Radiation Error (e2R)

Per Section 4.4.1, the radiation at the transmitter location is <L.OE04 rads, which is considered a mild environment. Therefore, the radiation effect is negligible per Section 2.1.3.B & D, so:

e2R = 0 mA [1a]

6.2.1.9 Seismic Error (e2S)

Per section 2.1.3.C & D, for normal errors, seismic events less than or equal to an OBE are considered to produce no permanent shift in the input/output relationship of a device. For seismic events greater than an OBE, it is assumed that affected instrumentation will be recalibrated as necessary prior to any subsequent accident, negating any permanent shift that may have occurred. Therefore:

e2S = 0 mA 6.2.1.10 Random Input Errors (a2in)

The random input error is the total random error from the flow element, which is the first module in the loop. From Section 6.1.1.6, c;l + 23.32 psid, [Ia]. Therefore:

a2in = Do I = +/- 23.32 psid [1a]

This is converted to mA by multiplying by the ratio of the spans, as in Step 6.2.1.2.2:

CC-AA-309-1001 Exelejam Revision 0 Nuclear Analysis No. QDC-0200-1-1369 l Revision 0 lT Page 24 of 33 l o2in' = (c2in)*(16 mAI300 psid) = (+/-23.32 psid)*(16 mA/300 psid)

=N1.24373 mA [II]

6.2.1.11 Calculation of a2 The total random error associated with the transmitter is determined below using the values calculated in Sections 6.2.1.1 through 6.2.1.10.

a2 = [4(RA2) 2 + (CAL2)2 + (ST2) 2 + (DRTY)2 + (e2T') 2 + (e2SP')2 + (e2V)2 + (e2R) 2 +

(e2S)2 + (a2in') 2]'/

= 4[(0.01333 mA)2 + (0.09304 mA)2 + (0.05333 mA)2 + (0.01600 mA) 2 + (0.02600 MA) 2 + (0.05360 mA)2 + (0 mA) 2 + (0 mA) 2 + (0 mA)2 + (1.24373 mA) 2])'

= i1.24994 miA [Ia]

Per Section 2.1.3.F, the allowable value (AV) is based on the combination of RA, CAL, ST, and DR. The random input error (o2in) is not included because this is based on the flow element errors, and is not part of the actual instrument channel calibration uncertainty, and so will not affect AV verification during calibration. Thus, a2AV = +[(RA2) 2 + (CAL2)2 + (ST2) 2 + (DR2) 2 ]f"

= 4[(0.01333 mA) 2 + (0.09304 mA)2 + (0.05333 MA)2 + (0.01600 mA) 2f',

= 0.10924 mA [la]

6.2.2 Non-Random Errors (e2) 6.2.2.1 Humidity Error (e2H)

The transmitter humidity limit is 100% RH per the vendor's specifications listed in Section 4.3.2. From Section 4.4.1 the upper humidity limit within the transmitter location during normal operating conditions is 90% RH. Therefore:

e2H = 0 6.2.2.2 Ambient Pressure Error (e2AP)

Per Section 4.4.1, the normal conditions at the transmitter location have a pressure of 14.7 psia. Ambient pressure errors are not stated in the vendor's specification for the transmitter, nor would any effect be expected for this type of differential pressure transmitter, therefore:

e2AP = 0 6.2.2.3 Process Error (e2P)

This is a sealed differential pressure cell transmitter that is connected to pressure taps across the main steam line venturis. The process error is included in the non-random input error from the venturi. Therefore:

e2P = 0 6.2.2.4 Non-Random Input Errors (e2in)

The non-random input error to the transmitter is the non-random error present at the output of the flow element. From Section 6.1.2.3, Eel = 0 e2in = Eel = 0

CC-AA-309-1001 Exelon.n MRevision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 Page 25 of 33 6.2.2.5 Total Non-Random Error (Ee2)

The total non-random error for the transmitter during normal operating conditions is given by the sum of the symmetric and bias errors as demonstrated below:

Ze2 =e2H + e2AP + e2P + e2in 1e2 =0+0+0+0 Xe2 = 0 6.2.3 Rosemount differential pressure transmitter static pressure span correction Per Rosemount Manual 4302 (Reference 5.7. 1), if a differential transmitter is calibrated with the low side at ambient pressure but will be used at high line pressure, the span adjustment should be corrected to compensate for the effect of static pressure on the unit. From Design Input 4.7, the process line static pressure is approximately 1005 psig. The desired differential pressure range is 0-300 psid. For Range Code 7, the adjustment is 1.25% of input/1000 psi. Thus, Corr factor= (1.25% input/1000 psi)

• 1005 psi = 1.26% of differential pressure input No zero correction is needed because there is no zero elevation or suppression, so the effect can be trimmed out after installation with the unit at operating pressure. The span adjustment is:

Convert 1.26% input span to % of output span: 1.26% * (16 mA) = 0.202 mA Add the mA correction to the ideal full scale output: 20 mA + 0.202 mA = 20.202 mA Therefore, for an operating range of 0-300 psid at a static pressure at the transmitter of 1005 psig, the adjusted calibration range at ambient pressure (0 psig) is:

Zero point: 0 psid input, 4 mA output Full span: 300 psid input, 20.202 mA output

CC-AA-309-1001 Exelemn >Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 Page 26 of 33 6.3 MASTER TRIP UNIT ERRORS - Module 3 Classification of Module Module 3 is a master trip unit (MTU), which receives an analog input from the transmitter, and generates a change of state in a discrete output when the input approaches the setpoint. Therefore it is classified as a bi-stable module. It has an analog input range of 4-20 mA (Input 4.3.3), corresponding to an operating range of 0-300 psid (Input 4.5) at the transmitter.

6.3.1 MTU Random Errors (o3) 6.3.1.1 MTU Repeatability (RPT3)

Per Section 4.3.3, the repeatability is +0.13% of span for temperatures between 60'F and 90'F. Per Section 4.4.2, the ambient temperature varies from 70 0 F to 80 0 F. Thus:

RPT3 = +/-0.13% * (Span) [2c3]

= +/-0.13% * (16 mA)/2

= +/-0.01040 mnA [lI]

6.3.1.2 MTU Calibration Errors (CAL3)

For the quarterly surveillance, the MTU is calibrated with the Rosemount Model 710DU calibration unit. The calibration unit provides an adjustable output current to the input of the MTU for use in MTIJ trip setpoint verification and/or adjustment. The calibration current is displayed on the trip/calibration current indicator located on the front panel of the calibration unit Readout Assembly. Per Section 4.6.2, the inaccuracy associated with the use of the calibration unit is included in the trip unit repeatability, so no other calibration error is required. Therefore:

CAL3= [ICa]

6.3.1.3 MTU Setting Tolerance (ST3)

From Section 4.5, the MTU setting tolerance is +0.08 mA, and is considered a 3o value, thus:

ST3 = +0.08 mA/3 = +0.02667 mA [la]

6.3.1.4 Drift Error (DR3)

Drift is calculated based on a 92 day interval plus a 25% late factor. This gives a total surveillance interval (SI3) of S13 = (92 days * (1.25) = 115 days From Section 4.3.3 the drift is included in its other specifications for up to 6 months (180 days). Therefore:

DR3*0 [Ia]

6.3.1.5 MTU Temperature Error (e3T)

From Section 4.3.3 the temperature effect of the MTU is included in the repeatability error determination. Therefore:

e3T= 0

CC-AA-309-1001 Exelon. Revision 0 Nuclear r Analysis No. QDC-0200-I-1369 Revision 0 l Page 27 of 33 6.3.1.6 Radiation Error (e3R)

From Section 4.4.2, the radiation level within the MTU environment during normal operating conditions is < I x I OE4 RADS TID. From Section 4.3.3, the accuracy of the MTU will remain within its stated repeatability within radiation levels. I x I OE5 RADS TID. Therefore:

e3R=O 6.3.1.7 Seismic Error (e3S)

Per Sections 2.1.3.C & D, the seismic error is not applicable, as noted below:

e3S = 0 6.3.1.8 Static Pressure Error (e3SP)

The MTU is not directly in contact with the process and is, therefore, not susceptible to errors induced as a result of process pressure variations. Therefore:

e3SP = 0 6.3.1.9 Power Supply Error (e3V)

There are no power supply variation effects stated in the vendor's specifications for this device. Per Section 2.1.3.D error effects associated with power supply fluctuations are considered negligible. Therefore:

e3V=O 6.3.1.10 Random Input Errors (a3in)

The random error present at the input to the MTU during normal operating conditions, 03in, is the random error present at the output of the transmitter and was calculated in Section 6.2.1.11 c;3in = a2 =+/- 1.24994 mA [1a]

The random error present at the input to the MTU due to the transmitter, a3inAV, used for calculating the allowable value, was calculated in Section 6.2.1.11 as o2AV.

cr3inAV = a2AV = 4 0.10924 mA [Ica]

6.3.1.11 Calculation of Total Random Error (Q3)

The total random error is the SRSS of the random errors from Sections 6.3.1.1 through 6.3.1.10. Therefore, O3 = + [(RPT3) 2 + (CAL3)2 + (ST3) 2 + (DR3)2 + (e3T)2 + (e3R) 2 + (e3S)2 + (e3SP) 2 +

(e3V) 2 + (a3in)2 ]4

= 4 [(0.01040 MnA) 2 + (O mA) 2 + (0.02667 MA) 2 + (O mA)2 + (O mA) 2 + (O MA)2 + (O MA)2 + (O mA) 2 + (O MA) 2 + (1.24994 mA)2 I]f

= +/- 1.25027 mA [l ]

Converting to psid by using the ratio of the spans as in Step 6.2.1.2.2:

o3p = (+/- 1.25027 mA)*(300 psid/16 mA) = +/- 23.44252 psid [1c0]

CC-AA-309-1001 Exel 6 n Revision 0 Nuclear l Analysis No. QDC-0200-I-1369 I Revision 0 l Page 28 of 33 l Per Section 2.1.3.F, the applicable uncertainties used in the determination of the allowable value (AV) for the MTU alone are a combination of RA, CAL, ST, and DR, since the mA input to the MTU is generated by the trip system calibration unit. Thus, a3AV = L[(RPT3) 2 + (CAL3) 2 + (ST3) 2 + (DR3)2 ]"'

= +[(0.0 1040 mA)2 +(0 mA)' +(0.02667 mA)2 +(0 mA)2 ]"'

= +0.02863 mA [la]

For the string calibration, the applicable uncertainties used in the determination of the allowable value are a combination of RA, DR, and c;3inAV, since CAL and ST are included in o3inAV. Thus, a3AVSTRINGA =+/-[(RPT3)2 + (DR3) 2 + (o3inAV)2f1'

= +/-[(0.01040 mA)2 + (0 mA) 2 + (0.10924 mAY) 21 '

= 0.10973 mA [ICY]

This is converted to psig by multiplying by the ratio of the loop input to output spans, as in step 6.2.1.2.2:

cr3AVSTRINGp = (+/-0.10973 mA)*(300 psid/16 mA) = +/-2.05744 psid [Icy]

6.3.2 MTU Non-Random Errors 6.3.2.1 Humidity Error (e3H)

There are no humidity related errors described in the vendor's specifications for this device.

Per Sections 2.1.3.D and 3.6, humidity effects associated with the MTU are included in the repeatability error determination. Therefore:

e3H=0 6.3.2.2. Ambient Pressure Error (e3P)

The MTU is an electrical device and as such is not affected by ambient pressure changes.

Therefore:

e3P=0 6.3.2.3. Process Error (e3p)

The MTU is not directly in contact with the process and is, therefore, not susceptible to errors induced by process variations. Therefore:

e3p= 0 6.3.2.4 Non-Random Input Error (c3in)

The non-random error present at the input to the MTU during normal operating conditions, Xe2, is due to the transmitter and was calculated in Section 6.2.2.5:

e3in=e2=0 6.3.2.5 MTU Total Non-Random Error (Ee3)

The total bias non-random error associated with the MTU for determining the calculated setpoint is:

Ee3 =c3H+e3P+e3p+e3in=0+0+0+0

= 0 psid

CC-AA-309-1001 Exel n su Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 l Page 29 of 33 6.4 TOTAL ERROR AND SETPOINT ANALYSIS Per Section 2.1.2, total error is: TE = 2cy + Ze. Because the setpoint may be checked by either application of pressure at the transmitter, or by reading mA at the MTU, values are calculated in psid and converted to mA.

6.4.1 Channel Total Error at MTU Output, TE3 The channel total error for MTU actuation, using values from Sections 6.3.1.11 and 6.3.2.5:

In operating psid: TE3 = 2*a3 + Ze3 = 2*(+23.44252 psid) + (0 psid) = +/-46.89 psid 6.4.2 Determination of Setpoint Since a rigorous drift analysis has not been performed for these instrument loops, the setpoint must consider margin. Therefore, the calculated setpoint is determined from the Analytical Limit (AL) and the total error as follows for an increasing setpoint. Per Reference 5.2, SPc=AL-TE-MAR The required margin, per Section 8.0 of Appendix A to Reference 5.2, is 0.5% of instrument measurement span. Per Section 4.5 of this calculation, the calibrated span is 300 psid.

Therefore the required margin is computed as follows:

MAR = 0.5% (300 psid) = 1.5 psid The values of the Analytical Limit and total error terms in psid are:

AL = 292.45 psid [Section 6.0] TE = 46.89 psid [6.4.1]

Therefore, the calculated setpoint, SPc, is:

SPc = 292.45 psid - 46.89 psid - 1.5 psid = 244.06 psid increasing SPc = 244.0 psid increasing (conservatively rounded)

This is converted to mA based on a 0-300 psid input corresponding to a 4-20 mA output, as:

SPcmA = (244.0 psid) * [(20 mA - 4 mA)/(300 psid - 0 psid )] + 4 mA

= (244.0 psid) * [(16 mA)/(300 psid)] + 4 mA = 17.01 mA increasing To determine the setpoint in terms of pressure input during calibration (SPccAL, with no static pressure present on the transmitter, for a 0-300 psid input corresponding to a 4-20.2 mA output:

SPCCAL = (17.01 mA - 4.00 mA) * [(300 psid - 0 psid)/(20.2 mA - 4.00 MA)]

= 240.9 psid calibration pressure increasing 6.4.3 Determination of Allowable Value Appendix C of Reference 5.2 provides the instructions for calculating an Allowable Value (AV) for an increasing setpoint as:

AV = SPc + applicable uncertainty Applicable uncertainty is a value calculated from the errors and uncertainties that have been determined to affect the trip setpoint at the time of the as-found measurement and is expressed as a 2a value, since these setpoints are considered Level l.

From Section 6.4.2 of this calculation, the calculated setpoint, SPc, has a value as follows:

SPc = 244.0 psid increasing For the string calibration check of the setpoint, the applicable uncertainty (au) is determined as the combination of MTU repeatability (RPT3), Drift (DR3), and AV random input error (a3inAV).

CC-AA-309-1001 Exe n Sm. Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 Page 30 of 33 auSTRING= o3AVSTRINGp= - 2.05744psid [Ia] [6.3.1.11]

Thus, the au is calculated as follows, in operating psid, to a 2a value:

In psid: aup (2() = 2 * (+/- 2.05744 psid) = +/- 4.11488 psid = + 4.1 psid Therefore, the AV is calculated as: AV < SPc + au In process pressure: AV *244.0 psid + 4.1 psid AV

• 248.1 psid The terms included in the AV determinations above were treated in the same way as they were in the setpoint determination. Therefore, adequate margin exists between the Analytical Limit and the Allowable Value, and no check calculation is required. The string calibration AV is conservatively used for both the string calibration (in psid) and the MTU calibration check (in mA).

Converting the AV from operating dP units to mA, based on a 0-300 psid transmitter input corresponding to a 4-20 mA trip unit input:

AV < (248.1 psid) * (16 mA / 300 psid) + 4 mA = 17.23 mA To determine the AV in transmitter input pressure during calibration, with no static pressure present on the transmitter, this is converted based on a 0-300 psid transmitter input corresponding to a 4-20.2 mA transmitter output during calibration:

AV < (17.23 mA - 4 mA) * (300 psid / 16.2 mA) = 245.0 psid 6.4.4 Determination of Expanded Tolerance (Administrative As-Found Limit)

Because the calibration check on this setpoint can be done as a loop, for the 24 month re-fuel cycle, and as the MTU only, as a quarterly check, an ET will be determined for both. First it will be determined in operating process units.

ET in psid for loop calibration Per Section 2.1.3.G, the Expanded Tolerance for the loop calibration from the transmitter through the MTU actuation is determined as follows (consistent with the method used to calculate ET for the ITS project):

ET = +/- [0.7 * (aup(2a) - ST)] + ST (where ST is 2cr)

ST2(3cr) = +/- 3.0 psid [4.5]

ST2(2a) = 2*(ST2(3a)/3) = 2*(+/- 3.0 psid)/3 = + 2.0 psid aup(2cr) = 4.1 psid [6.4.31 ET = +/- [0.7 * (4.1 psid - 2.0 psid)] + 2.0 psid = +/- 3.47 psid ET = + 3.4 psid (conservatively rounded)

In order to evaluate the computed ET value, two comparisons are made. First the Expanded Tolerance must exceed the 3a value of the Setting Tolerance.

In psid: ET (3.4 psid) > ST (3.0 psid) PASS Secondly, the actual setpoint, plus the Expanded Tolerance, must not exceed any applicable limit. The only limit of concern here is the Allowable Value. Per Section 6.4.2, the setpoint in terms of operating dP is 244.0 psid. Pcr Scction 6.4.3, the Allowable Value is in terms of operating dP is 248.1 psid.

SPc + ET = 244.0 psid + 3.4 psid = 247.4 psid < AV (248.1 psid) I'ASS Therefore, the ET is acceptable as defined at a value of 3.4 psid.

CC-AA-309-1001 Exekon.. Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 Page 31 of 33 ET in mA for MTU calibration Per Section 2.1.3.G, the Expanded Tolerance for the quarterly functional check of the MTUs is determined as follows (consistent with the method used to calculate ET for the ITS project):

ET = +/- [0.7 * (aut,,(2a) - ST)] + ST (where ST is 2a)

For the MTU calibration check, the applicable uncertainty is determined using a3AV from Section 6.3.1.11, which is based on the combination of MTU Repeatability (RPT3), Drift (DR3), Setting Tolerance (ST3) and Calibration Error (CAL3).

a3AV(la)=+0.02863 mA [Ia] [6.3.1.11]

Thus, the au to 2o is calculated as:

attA(2 a) = 2 * (a3AV (I a)) = 2 * ( 0.02863 mA) = +/- 0.05726 mA From 6.3.1.3, ST3 for the MTU alone is ST3 = +/- 0.02667 mA [I a]

ST3(2a) = 2*(ST3(l c)) = 2*(+/- 0.02667 mA) = +/- 0.05334 mA ET = +/- [0.7 * (0.05726 mA - 0.05334 mA)] + 0.05334 mA = +/- 0.05608 MA ET = +/- 0.05 mA (conservatively rounded)

In order to evaluate the computed ET value, two comparisons are made. First the computed ET must exceed the 3a value of the Setting Tolerance.

ET (0.05 mA) < ST (0.08 mA) FAIL Therefore, per Section 2.1.3.G, the ET is set equal to the ST of +0.08 mA, so ET = +/-0.08 mA.

Secondly, the actual setpoint, plus the Expanded Tolerance, must not exceed any applicable limit. The only limit of concern here is the Allowable Value. Per Section 6.4.2, the actual setpoint is 17.01 mA. Per Section 6.4.3, the Allowable Value is 17.23 mA.

SPc + ET = 17.01 mA + 0.08 mA = 17.09 mA < AV (17.23 mA) PASS Therefore, the ET is acceptable as defined at a value of +/-0.08 mA.

ET in mA for transmitter calibration Per Section 2.1.3.G, the Expanded Tolerance for the transmitter calibration is determined as follows (consistent with the method used to calculate ET for the ITS project):

ET = i [0.7 * (aup(2a) - ST)] + ST (where ST is 2a)

ST2(3a) = +/- 0.08 mA [4.5]

ST2(2a) = 2*(ST2(3a)/3) = 2*(+/- 0.08 mA)/3 = +/- 0.05333 mA For the calibration of the transmitter alone, a,,r,is conservatively based on the a2AV from 6.2.1.11, where a2AV = +0.10924 mA (Ia).

au"xr(2a) = 2

• a2AV = 2 * (0.10924 mA) = 0.21848 mA ET [0.7 * (0.21848 mA - 0.05333 mA)] + 0.05333 mA = + 0.16894 mA ET = +/- 0.16 mA (conservatively rounded)

The transmitter ET must exceed the 3ay value of the transmitter ST, from 4.5.

In mA: ET (0.16 mA) > ST (0.08 mA) PASS

CC-AA-309-1001 Exekni. Revision 0 Nuclear Analysis No. QDC-02004-I1369 I Revision 0 l Page 32 of 33 7.0 RESULTS & CONCLUSION The calibration information used to support the results of this calculation is defined below. In addition, the calibration values and expanded tolerances are identified.

7.1 Main Steam Line High Flow - Instrument Loop Setpoint Requirements:

% Rated Flow Process Differential Trip Unit (Note 1) Pressure Calibration Analytical Limit (AL) < 140 % 5 292.45 psid Allowable Value (AV) <= 134 % <248.1 psid < 17.23 mA Setpoint (SPc) 133 % T 244.0 psid 1 17.01 mA T Rated Flow 100 % 111.06 psid Note 1: Approximate % rated steam flow values for AV and SPc were calculated using the equations in Section 6.0 and are provided here for reference only.

Note 2: Section 6.1.1.1 utilized a conservative Base Uncertainty for the Flow Element that bounds the reference accuracy value of FE 2-0261-IA defined in References 5.16 and 5.17. As a result, the setpoint of the associated DPIS 2-0261-2A-1 is not affected and no change is required.

Note 3: An amendment to the Quad Cities Technical Specifications is required prior to implementation of the above setpoint requirements. Technical Specification Table 3.3.6.1-1 Item 1.d and Table 3.3.7.1-1 Item 3 must be revised to specify the Allowable Value for Main Steam Line Flow - High as < 248.1 psid and to add a surveillance requirement for trip unit calibrations on a 92 day frequency.

7.2 Surveillance Intervals, Setting Tolerances and Expanded Tolerances:

Surveillance Interval Setting Tolerance Expanded Tolerance Transmitter Calibration 24 months +/- 0.08 mA +/- 0.16 mA Loop Calibration: 24 months +/- 3.0 psid +/- 3.4 psid Trip Unit Calibration: 92 days +/- 0.08 mA + 0.08 mA 7.3 Transmitter and Trip Unit Calibration Requirements:

The following values define the calibration requirements for transmitters DPT 1(2)-0261-2A through

-2S (excluding -21, -20, -2Q), including a static pressure correction for the 1005 psig steam line maximum operating pressure:

% of Span Transmitter Input Transmitter Output 0 0.0 psid 4.00 mA 25 75.0 psid 8.05 mA 50 150.0 psid 12.10 mA 75 225.0 psid 16.15 mA Setpoint 240.9 psid 17.01 mA Allowable Value 245.0 psid 17.23 mA 100 300.0 psid 20.20 mA

CC-AA-309-1001 ExelmnS. Revision 0 Nuclear Analysis No. QDC-0200-I-1369 l Revision 0 l Page 33 of 33 The following values define the calibration requirements for functional testing of trip units DPIS 1(2)-

0261-2A-I through -2S-1 (excluding 1, 1, -2Q-1):

% of Span MTU Input MTU Indication 0 4.00 mA 0.0 psid 25 8.00 mA 75.0 psid 50 12.00 mA 150.0 psid 75 16.00 mA 225.0 psid Setpoint 17.01 mA Not Applicable Allowable Value Not Applicable Not Applicable 100 20.00 mA 300.0 psid 7.4 Due to the replacement of the DPISs with Rosemount transmitters and Master Trip Units, upon implementation of ECs 345323 and 345324, the current versions of the applicable calibration procedures (References 5.4 & 5.5) shall be revised to follow a similar approach as that used for the other analog trip loops. Specifically, in order for the results of this calculation to remain valid, the following must be true:

7.4.1 For the channel surveillance, after calibration of the transmitter, the actuation of the trip unit must be verified by observation of MTU trip based on increasing pressure input to the transmitter, using the setting tolerance given in 7.2 above.

7.4.2 For the master trip unit surveillance, a certified digital readout assembly for the Rosemount 710DU Trip/Calibration system must be used to generate an increasing stable current and to observe the trip current, to the setting tolerance given in 7.2 above.

7.4.3 The pressure input to the transmitter must be measured with either the M&TE listed below, or other M&TE of equal or better accuracy than the worst case unit (Heise CMM - 400 psig).

M&TE Accuracy at 104'F (Ref. 5.9)

Heise CMM (400 psig) t 1.744484 psig Druck DPI 601 (500 psig) +/- 0.730068 psig 8.0 ATTACHMENTS Attachment A- GE SIL 438, Rev. I (Ref. 5.6) - 3 pages Attachment B- BIF Vendor Information (Ref. 5.18) - 4 pages Attachment C- BIF Vendor Letter (Ref. 5.17) - 3 pages Attachment D- Rosemount Letter (Ref. 5.22) - 2 pages Attachment E- Rosemont Telecon (Ref. 5.23) - 2 pages Final

[Last Page]

- - - , .' I' -

Aay I102 INA SIL GEcjuclearEnergy Services Infonnadon Lerer Main steam line high flow trip setting SIL No. 423 The original SIL 43S -s wnitten because a re- steam lines crning approximately 133 Fa of its Revision I view of the MSL high flow trip sepoint for an normal flow at 1005 power.

ooenadng BWR disclosed an inconsistency be-Many plant technical specificadonsost -I , set-1Y.E, 394 oween :me acu! settncg and thar spe-led in -e pain; .or thr XSL high fow n.ip based on ar.

plant technical specincadions. The difference -- s ucoer analvtical limit of eauivalent to 140% NBr a-bu:ed to the use o. design stea flow co.ei-stear flow. 7.ae acual sepoint is then calculated dons rther than rated conditions in the ori-.nal as a maximum pressure drop across the dilfer-n-semoint calculation. The original SE. 438 in- ial pressure sensing device.

formed BWR owners of this potencial inconsi-tency and provided a method for determining An inconsistency was discovered in one i.ns;nce the proper setnoint for the MSL high flow nit. in which th- calculated diferential pressure set-point ,as based on the design steam flow condi-This Revision I to SL. 438 correcm an e:-.or in tions For the turbine (105% NER steam flow) the equation for calculating the NiSL high flow rather than the rated. licensed power conditions trip semoinr. Using the uncorrected equation for the nuc!ear boiler. This resulted in a differ-found in the original SE. 438 could result in a enial pressure serooint that corresponded to non-conservatsm of aoproxiinamly 3% stea approximately 147 % NBE steam flow, which is flow when calculating the analytic limic or nr.p inconsistent with the plant technical spec:fica-serpoint.

cons.

Discussion The safet! significance of this potential inconsis-The ?Main Steam Line (MSL) high flow sensors tencr is a slight L rease in the maximum detect-detect and isolate breats in the main steam lines able st=ea line break size as detected by the outside the reactor connminment. The high Eflw stea line di.Ferential pressure sensors. There trip initiates reactor isolation by closing the main are additional leakage detection monitors which Steam isolation valves (MISIV) to minimize poren- would also initiate stea line isolation. Without dial release of radioactive materials to the envi- reliance on these additional monitors. a conser-ronment. vative evaluation of the high setpoint demon-saraes cha; the serpoint difference results in less The trip signal for the MSL high flow isolation is than a ten cercent increase in released radioac-tiken from differential pressure instruments in tive materIal. which is significandly less than the the now limiters (vencuris) in each steam line. IOCFRI00 limits. Because there is no significant The vencuris also Limit the maximum flow loss change in the margin to allowable limits. the from a steam line break to approximately 200 %C higher sercoint is not a safety concern.

of rated steam flow for that steam line. The maximum serpoint for the LMSL high flow c:.p Recommended acion must be Iess than the maximum flow (choke CZ Nuclear Energy recommends that owners of flow) calculated for each steam line, and the CE BWRs verify that the proper instrument trip minimum serpoint should be sufr-ciently above secpoint has been established. The following 100 % of rated steam flow for each steam line to method is recommended for determining prevent spurious trips. A typical sempoint whether there is an inconsistency between plant (analytical limit) is 140 % Nuclear Boiler Rated technical scecificatons and actual trip serpoints.

(NBR) steam flow. tnis setpoint permits on-line The calculated differential pressure at the flow testing of the MSIVs. because closing one valve rare corresponding to the MSL high flow crip would result in each of the remaining three Calculation QDC-DZ00-t-1363, Rev. 0 Att:irhment A Piae Al nF AA

SIL No. 438 Revision I *page 2 secpaonc allowed by the technicll specificadons may be checked against the acnual tip scrpoint.

The equation for calculating this flow -ate is shown in Atchment 1.

T-o receive addidonal infor-iadon on this subject Technical source dadon. please conmct your local GE Nuclear En- M. _. Drscoui eryv Servic: Reoresendaivc.

This SL cperairis onlv co CF BWRs. The condi-dons undcr which GE Nuclear Energy issues Sris are smated in SIL No. 001 Revision 3. the provi-sions of which are incorporated into this SIL by reference. R. M. Fa=r:cld. TIgram Manager Service Information Communicatons Product refsrsncs GE Nuclear Energy B21-Nudelr Boiler 175 Curmier Avenue. SanJose. CA 95125 Calculation QDC-02G0-l- 13G9. Rev. 0 Attachment A, Page A2 of A3

Attachment I to SIL No.438 Revision I -pageAI Calculationof main steam line high flow trip setpoint Ten equationl for calculating the main steam line high flow trip sccpoint is:

W- 18900- C/d1 F (pt &P)'t where:

FI 11 k 1-r' l-BA XIkTX 1-r IXl(B'&r~J W = steam flow rate at desired analytic limit or trip setpoint (lbm / hr)

C = coef.icientof discharge (O.995 for a venturi tube with a machined entrance cone) (ratio)

B = ratio of throat to pipe inside diameter, d I D D = pipe inside diameter (in) d = throat inside diameter nm)

F = area thermal expansion factor (ratio)

(Approximately 1.0092 for 300 series stainless steel primary element thermal expansion from 68aF to 5 500F) p = upstream fluid density Obm / ft'). (rated condition of dry, saturated steam) r = ratio of throat static pressure to inlet staic pressure p (absolute pressures) k = ratio of snecific heats of fluid, C7 (isentropic exponent for ideal gas, approximately 1.255 for dry, saturated steam at 1050 psia and 550'F)

AP = differential pressure across venturi P, - P, (psid)

Y = expansion factor for a gas (ratio) 1 Asnenican Sociecy of Mechanical Engincers. 'Report of ASME Research Comnmittee on Fluid Meters'. Sixuh Edition. 1971, P. 23;, and May 1974 Errata.

Calculation QDC-C2OO-I- 13G9, Rev. 0 Attachment A, Page A3 of A3

-)Z.. , - - - .., , I :-, E'd: N",1i Ti;i Ij P - L:- ) = 7 = -. -Z- -:,: - .- ,] -. : = - -: 0 = -1 -=

- :t-c-_---

-A5HOLT-1 71 7 73.

he LH:5gh Street Furnace Ccrn- ^e.-ce.- .theec-sso-; - _-r;r.c

Ps li.tle rr.crB -,an a

_anv, to -naZie use cr .. e 1- V-,.:uri tuze as a :lce

. ,; F _ kcsmith shco vinen it ^ecan measuremr.n zoo;. '.irenu. '_ces and met.ers

.crcducing iron clows z have been t.va cf ='rs .. cs;t rm,-ccr-ar.a

_______ l irc'dicence around 1_0.

SCIo 'o th.e r.ewiv mncor- A !

_cra_'-_ Suilder's !rcr, Focundrir. 1_ i .

. wo;ners acced -rccuczts w.rc.^

- r.c -.cre ;zrmise cf gro.vwt Srcd -Miio- .-.Z I

-e iec:ed ;.heir own areas cr ex-er.-se. I.

, s stated purpose at inccr

cra::cr.

-:as:. e "manuftactre c, irzn .cr.s .c'--:ses

_,-c *;ner cast;r.gs ,cr buflcers anc c;ner I uses.' E.ramples cf the cornamental ir:rnwcr'.

Molor -Jzq -qurnzv,:." :cr E331 jr3dy ',Vl:sr :.I

rcc.:ced 7.i! '-- ,e by ElF during thje mid I1ECC's can n '.e Urrar cr Ccr.,ress prcducts ever sincs.a.' :n4linu.in decica:icn -^

Euildingc in Washington. Other croducc s -rc- u;Cgradi r. :.- ese prcruors . tIr c s r-sear cucsc _vy SlF during tha: -ericc irc:_cez _-.C deveiocm.er.. -.  :.._~ _z;ersal i-z:ur~i cvlincers fcr bridge piers and Prrefabricae_d Tuce in :1C70. Az ;,-e tm,.e zf ,s introc_c:,icn, ig,;n:cuses lewhic.. were irstailed arcund the t.e U T Was the -esuit,cf :.,cusands c. hcurs vcrld. of designrencieerngr. andciccrcus h"&- _ic 7.-.e cemand .zr clFs arc.-itecturai r-.n tesding. The VT7 zrea::vi irvcr-asec he rei;a-ceclined as s-eel came into more wiccread biility and acz urac'iorv _iw measurement. :.

use and cecorative iron lell cut of fasnicn. t..e same ime, the 'W/.._rducecd costs of boct.

Less rescurceful firmis might have icided. but ,ead-in -icing anc sLrrcundinc structures -v EiF resondcecd by Entering into rmarkets eliminating th.e pre'icus recimr-.: .cr `.C n-deecing -rcductvs which cculd te r-.ar.Lac- rur.s cf straight cicze .n:= a Venturi.

red w^th -etncds and materials similar to

,thcse =IF had been using. Cne cf -the Icgical Mlore than 16C ;ears '-ave cassec -irce tran.siticns E1F made at that time inrcuded the High _;.eet .r-a- zcmzcany -r::uccz cnanging production from ircn arc.itec:ural its first ironr. d . :s suc-columns co cesscr, SlC, has success- 7 .,

fully desigred. mar.iac- .

warer pipes. tured, and rmarketez a -

In 1887 sceadily evcl'ing -roCuc :t Clemens :Her- line cr ov'er 13 d-caces. a , e.

schel intrCduced Tccay EIF, a Unit cf rer-l - . -

the Herschel Signal, is recognirec wcr!C .

Standard len- w.ide as a leader in autc-t'ri. by far the m.atic flcw control, .r c-r.- _: C' most accurate trolled feeding ard wveighing ilcwmeter avail- cf liquids and solids. and in vasteva,-r a.cd able over the water treatrment syst-r.ms.

ensuing E0

-' ,- years. In 1893

'he Chief E;

.4 XF 11CM-1cuse. atr lum Isand. in %or.'.,-

anvorf 3j 4 .1aer ,14wocr. Rtl Ifl311eai.1n gineer at clF.

339 Jrd 004ratioaltat v-or 204y~or.a F. N. Conne:.

1 233 D PAGE 2 SERIES :le UY7

(:3lculaftio QDC.'.'((4-t I iG-?. P.V: ')

-:.:,; It Attzachmvit 13. Page B1 oCB4

. GENL SIG/LEEDS 8 NORTHRUP 21E D- 39193=350 0005594 S Fc-cloa5 THE RIGHT FLOWMETER FOR EACH APPLICATION Calculation QDC-OO20-l- 1369, Rev. 0 Attachment 13 Page B2 of B4 SlF has the experience and ex- I r 7

• *.t Fr. I *I oiil. ,ll* li pertise to approach arny applica-tion with the confidence that Standard Srzes 1ac we have solved the problem eftcre. We can handle the jcb , rr tn an an smawor wlrtj .%mjin..

economically and reliably. We A On c s. rodoi Isacro.kator .a::,t3Js,..

do not consider any applicatIcn ,twt 3 n M. ltnr cmalrtcnt%.rGC =St fron tco diflicult or tco simple, too tne-alilc"Or"m 12rse or too sm all. ,t*2z@ttr *.

t.sOShZ6teJr~ai~,

Here is a partial list of appli-cations where BIF flowmeters . ....

are working: . . - . . ctangular uvr.

• Water intake metering for  ? ne New York City; 96" line size e tanfdngIastewmance sc~Caoofthr Mat bstn IJ~r. hsav zJon devloood to motor annealed air l.

• Primary metering equipment OrCese MeW"Cwqulatr r"Is t ot ,

for the first fertilizer plant t6Cta ufnounnefrri olnt' built in the People's Reoublic w ~of China. of Chna .Made[ 183 WeidmentType

• Chilled water metering in the World Trade Center's air conditioning system _ C ytUC" WOt0C42 C1.

_ot srenin uz ler Clon ion at carcsicniostistant

• Eoller feed water metering onotals.Saaesstre r-104dtoT frme in nuclear reactors r *I1 _ IctC In0nh0irc Zn(CLe

rVIWS d at

• Compressor surge control in air reduction systems

• Air flow measurement in .. . Plastic UVT Insert Mcder 182 heating ducts

• 'bhfito- heail %is. nihosti sl Curbcy retailrem"Isaare

• Fire protection systems to 1tl0N S Wa 'Otf 1IU,!O provide the ability to verify 1bfdf tar 1a0 r= "ra:Ogy'>eldl"'

31'M Ifl 3 pump outputs during flow lb"n teoltqltWronictagL acrt@seeIonte"u4nrart the 3 tests ine at t Rrnz Olle ksnt-so sat *wbmel or foundationa rSaulreC.

• -IFUVTs are used by the majlority of pump manufac- ~RneMtrn ytm turers to Insure the accuracy . Yde Range Metering Systems of their pump test stands h_Th.

Utnimvr VArn. MiElnt Valve in sieirle w"T a Wnhtd Verldtu1ypab. woaes 3*1 311*1iflq 11110. Ccoion now t11ms Builders Iron Foundry, .dr aescoo

, to atlwt rY e Providence, RI, eYcond rmaiw" i 3valve Is flttof C OmOtVo210% Cl rei lM.

_ about 1885. are tUn*wf-WI U

m'A". tra a u. h 0I e CIA:of 1 l the

. So- 10 IC% e:1% seal-P.c" AccuiJ4lCwo oPug jt we"Tma..kreod ffre sr. .o uvr.by the UVT.

APPLICATION SERIEI80 UVT . REF. IO2- . PAGlz 1234 0-11' CZ'EIVA~ 51iI.I'CCAP/ LEEOS Ak,KCHRuP

GENL SIG/LEEDS a NORiTHRUP 2cE D M 39193-50 0005595 ? W F-ob/-C5 CHARACTERISTICS OF THE UVT 0

The Universal Venturi Tube is Possible Savings In Pipe (Pipe Dlarne the primary meter which pro- 30 25 20 i5 10 5 0 30 25 vides the best performance characteristics found in other I. I ._ I ElF UVIT C

flow meters.

• Heavily documented, II_

I _

1 I I ASSICALlVENTURI 1 C1 c FWOW TUSE § I =

accuracy I I l; -- I L SME TYPE NOZLEM W

• Lcw head loss and there.cre lower operating cost I ORIFIE PLA~ I

• Short laying lengths: i i ASMEm PTC- DW OTESSE=CN L approximately 2.5 pipe Cinf-ansen Zr meref run fenorns mxuhted toe v,'afIoc od en'ojtmnce ol ytflOus f,`* Of 'fmmae,dq diameters long

• Low installed cost. reduced amount of upstream pipe -

I I

and associated laying costs ,.., 53

-0 : .22 4

F. ~-

I,^>1 6o; a

cs r3 7;2 C..1 02 I*2C

, Varicus materials of con- u> Cu.

struction available Cocumemteo Ac:urac-y I L 1..2 (J I I i I i

. Meters liquids and gases - EnVSgY ES1!Vant I (DI 010 I 01 _I I O I O I O the only meter with docu- N-iglig:tle rnsuaclaion tc: I: IO I I I 0 I I I Adautsole to G4a 0 js Ficw I mentation available; verified at Colorado Engineering Flt!d Car:!Nale I 9 10 1 1 0 0 O I I St:tJI .S. _: O I I I E:-eriment Station, Nunr, InoensrUIe to AsIg I a ICI I I I 1O Colorado E=-tr14nCsO Manufmtc:ure I 3 I 0 1 0 1 0 1 0 1 0 1

• No line size llmit- Us on solids a..lrq nutat z I010  ; 0

,i - .;.,  ;,: ., A,,g--;s_ .

.. 7.t Calculation QDC-CZ00-I- 1369, Rev. 0 Attachment 6 Page B3 of B4 p ,, _ -

t.

=

• 11

,_1 INUNE BARSTOCK INSERT OESIGN IN CONTAINING PIPE Line Sizes: 1 " through 6" Line SIzes: 8" and larger Line SIXeS: C

-; , ' . *7 t_. *.- . --

-7 - - - . .

PAGE 4 SERIES 180 UWT REF. 180.2C-4 CHARACTERIS .ICS 1235 CELERAL S;C4AI C-RP/ LEEOS k NOR UP

-GNL SIG/LEEDS a NORTHRUP 21E D

• 3919350 0005596 9i F-o-os 0 FLOW CONDITIONING: THE KEY TO RELIABLE FLOW METERING I~rs) +/-0.g without calibration, and: Frinally, it re-examines Flow in 20 1S 10 5 0 we have documentation tg its throat sec:icn. This error-prove mi. . Fpurging process provides a I I _ I___ I____ L_VT_

Unlike other differential measurement resulting frcmn I______I JLASSICA4VEINTURI I producing meters, the UVT the difference in the kinetic doesn't have to accept the energy of the flow at the ..iiet I F1bw TueE I inconsistencies of poOr velcc- and the throat.

I! I NZZ~ ity profiles in a flow line. The UVT first samcles the flow, in its inlet. It then accelerates and cn~ilns/ .f ) s

as wnn4ns18Cfj( jawn rwiamofJ£h1T tredUS 3lbow..low. the UVT's unique, patented in-ternal hydraulic contour c-r ditions fluid flow, providing accuracy and rEliability not previously possible in primary \t.lstCdW It ntidYxz meters. The UVT design builds .l ,)N ." M4 R in flow conditioning; flow is . 2 -; ,

hydraulically cushioned to provlde a strong, stable, pre- r.

cictable, low-noise signal. 21-_

UVTs guarantee accuracy ot.

• thdroughly '

• Invostsqatad and dccrtr.&n1t .:e- . * - -.  ::  :-

.. - - Caicularion QDC-C200 t369, Rev. 0 i Atachment B Page 64 ofE4 A T INLINE CAST IRON INLINE FABRICATED through eo" Line Sizes: 2" and larger Una Sizes: 8" and larger FLOW CONDIT1ONINW SFRIES 180 UVT REF. t80.2-4 PAGE3 1236 0-13'

,.F,'kRA Sh-I Cr..RP/ I FFM ', '1CRf'IK P

B I Fe obc-o0200-I- 1369 If ev' C)

EngineeredFlow Applications . At etc.. k K C C

• SAC Cl of C!

July 17, 2002 Mr. Jeffrey Drowley Mechanical Engineering Manager Exelon Nuclear 4300 Winfield Road Suite 300 Warrenville, IL 60555 Mr. Drowley, After phone discussions with Mr. Joseph Basak and yourself on Friday July 12'h and Saturday July 1 3 :h regarding the damages to the Alpha Steam line Venturi at Quad Cities II Nuclear Plant, I was asked to come on site. The on-site stay was to expedite the assessment of impact on the Choke Flow requirements, the safety set point requirements and the flow measurement requirements of the BIF supplied Venturi as a result of a Dryer Part Separation.

While on site I have had discussions with several plant personnel, contractor service people and GE Team people working on this outage. I have reviewed, for several hours, movies taken of the Venturi impact areas and of pieces that were lodged in the Venturi or that passed through the Ventuii. .. .,

were taken with two different cameras. Much of the upstream pipe, the Venturi element itself and the area downstream on the Venturi were made visible. Most importantly the Venturi hydraulic shape was visible. Initial viewing was of the Venturi with a piece of foreign material lodged in the thr.. t -:

movie several impact areas were visible on the surface of the elliptical approach section. In later movies we saw the same impact areas and areas further downstream of the Alpha Steam line Venturi.

We also saw movies of the Bravo Steam line Venturi. The views of both Venturi were from just above the High Pressure Piezometer through the Venturi to past the Hydraulic Shape downstream weld that supports the shape.

The impact damage area of the Alpha Steam line Venturi lies mostly within the elliptical approach section. The damage ranges from what were categorized as stains (no discernable depth) to slight scratches (0.0005" to 0.005" depth) to pits (diameters of -3/32" with depths of 0.01" to 0.02") and gouges (long lengths up to 2.5" long with depths of 0.02" to 0.10"). The dimensions shown above are estimates based on other known items within the camera view and were not physically taken.

No impact damage was discemable within the Venturi throat itself. However an unidentifiable discoloration of about 3" diameter existed around the throat piezometer hole. Although unidentifiable this does not appear to be a result of the recent damage and will not affect the performance of this Venturi.

B I Fe 30685 Solon Industrial Parkway Unit F,Solon O1- 44139.4331, U.S.A. (440) 519.BIFI (2431)

....... _..L:r..._._- FiY JfllQ RIF'){v412)

B I Fe arc 0 n- S. 1369 Pc,. 0 EngineeredFlowv Applications A ft-zkL e1 t eC

)- oF C3 There appeared to be a few slight scratches in the recovery cone of the Venturi, which have no real impact on performance.

The Venturi Flow Equation contains several terms covering density, pressure differential, expansion factors, flow rate, throat diameter, inlet diameter and Discharge Coefficient. The throat diameter-and inlet diameters were not changed as a result of this damage. The density and expansion factors will be whatever they are as a result of the steam temperature from normal operations. The pressure differential and flow rate are related to each other via the Discharge Coefficient. The pressure differential is read with instrumentation and the flow rate calculated for that pressure differential using the Discharge Coefficient. The Discharge Coefficient, however, is what will be impacted by this damage. Both the general diversion of the normal flow-streamlines expected into the nozzle, and the increase in the frictional resistance loss between the Inlet Piezometer and the Throat Piezometer, cause this. It is important to know that the most sensitive area of the Venturi is the Throat Piezometer hole area. Sensitivity decreases as you move upstream from the throat toward the upstream edge of the hydraulic shape. Similarly, the Inlet Piezometer area would also be sensitive but not as sensitive as the Throat Piezometer area.

It is my experience as a result of reviewing thousands of laboratory calibrations of Venturis with varying frictional characteristics and shapes that this total damage (Attachment I) will no; caS. -

than a +O.5% change in the uncertainty to the normal assigned discharge coefficient uncertainty level.

The damage that I view as having the greatest impact is what we are referring to as Gouge 1. While nct near the sensitive area of the throat, it is in a direct line with the Throat Piezometer hole an.!; -I_

have the largest effect.

The impact on overall permanent pressure loss across the Venturi as a result of the damage is undetectable and should not impact plant performance.

There appears to be a minor circumferential depression at the entrance to the elliptical section. I believe that this was caused by impingement of condensate on this surface over the past thirty years of service. There appears to be no depression near the pipe wall, in the boundary layer region. Most of the depression occurs as you move beyond the boundary layer into the ellipse but still at a severe elliptical angle. As the elliptical angle relaxes, the material depression reduces back to the original shape, as it is no longer visible. This appeared in movies of the Alpha Steam line as well as the Bravo Steam line. This shows that this depression is not caused by the Dryei Incident.

My experience with Venturi at BIF, The Foxboro Company and Westfall Manufacturing cov.es 25 years with Venturi and Flow Meters of many types, configuration and service. I worked for BIF and certified the flow calculations for this Venturi when it was originally supplied to General Electric for this plant.

B I FR 30685 Solon Industrial Parkway Unit F. Solon OH 44139-4331. U.S.A. (440)519-BIFI (2431)

... . .,.., k _.. e..,..

-nm Fax (440) 5 I9-BIF2 (2432)

B I Fe Engineered Flow Applications QtC -c200-f e.c4 13-69 zev. 0 C3 o4 C3 I do have some concerns regarding accelerated erosion of the material as a result of this recent surface damage. However, in discussion with members of the GE Team, they believe that the material is sufficient and specifically chosen for its erosion resistance.

I recommend that a comparison of flow signals be performed at known power levels and any changes trended to indicate potential problems. These trends may be used to trigger a closer inspection of the impact damage area at the next scheduled outage with comparison to the pictures documented during this outage for any changes. The same people should review any visual inspection, if at all possible.

As a result of that visual examination, a disposition may then be made to either replace the Venturi, perform another visual check at the next planned outage or to skip the next planned outage and do the visual inspection within the following planned outage.

Recommendations:

The normal Discharge Coefficient uncertainty be increased by 0.5%.

During the next startup, look at the hydraulic noise level of the flow signal of the Alpha Steam line Venturi. Compare it to that of the Bravo, Charlie and Delta Steam lines. Compare it to what the experience was before the initial event that triggered this shut down. This may be used to coni n crns effect on sensitivity and make appropriate setpoint changes as required.

Compare the flow readings of the most recent startup to the next startup as the unit comes up to full power, being sure that the flow rates look normal considering hydraulic noise as well.

Consider having a replacement Venturi for the Alpha Steam line available as a contingency for the next outage. Although I do not believe a replacement is necessary at this time, this Venturi will take time to manufacture and that time would impact the length of the outage. I estimate that the expedited lead time for a replacement Venturi would be 9 to 12 weeks after Purchase Order and design release to manufacturer.

BIF was very happy to help with this outage and if we can be of any assistance in the future please do not hesitate to call.

Sincerely, Joseph M. Motta Senior Flow Engineer B I Fe 30685 Solon Industrial Parkway Unit F. Solon OH 441394331, U.S.A. (440) 519 B3I17 (2431)

., I.- . . * :-L:1. .. ... ......... Cow{J} CI0 nils {la1v1

Rosemount Nuclear Instruments Rosemount Nuclear Instruments.

1200I TeChnologq DOve Inc.

Eden Primne. MN 55344 USA Tel 116121 828-8252 4 April 2000 Fax 116121 828-8280 Rcr. Grand Gulf Nuclear Station message on INPO plant reports, subject Rosemount Instrument Setpoint Methodology, dated March 9,2000

Dear Customer:

This letter is intended to eliminate any confusion that may have arisen as a result of the reference message from Grand Gulf. The message was concerned with statistical variation associated with published performance variables and how the variation relates to the published specifications in Rosemount Nuclear Instruments, Inc.(RNII) pressure transmitter models 1152, 1153 Series B, I I 53 Series D, 1154 and 1 154 Series H. According to our understanding, the performance variables of primary concern are those discussed in GE Instrument Setpoint Methodology document NEDC 31336, namely I. Refercnce Accuracy

2. Ambient Temperature Effect

3. Ovcrpressure Etfcct

4. Static Pressure Effects S. Power Supply Effect It is RNII's understanding that GE and thc NRC have accepted the methodology of using transmitter testing to insure spccifications arc met as a basis for confirming specifications are

+30. The conclusions we draw regarding specifications being +3a are based on manufacturing testing and screening, final assembly acceptance testing. periodic (e.g., every 3 months) a testing of transmitter samples and limited statistical analysis. Please note that all performance spccifications arc bascd on zero-based ranges under rcefcrcnce conditions. Finally, wc wish to make clcar that no infecrcnces are made with respect to conridence levels associated wi.'i any specification.

I..Rccrence Accuracy.

All (100%) RNII transmitters, including models I152, 1153 Series B, 1153 Series D, 1154 and 154 Series H, are tested to verify accuracy to +0.25% of span at 0%, 20%, 40%, 60%,

80% and 100% of span. Therefore, the reference accuracy published in our specifications is considered +3c.

2. AmbientTemper ture Effect All (100%) amplifier boards are tested for compliance with their temperature effect specifications prior to final assembly. All sensor modules, with the exception of model 1154, are temperature compensated to assure compliance with their temperature effect specifications. All (100%) model 1154, model 1154 Series H and model 1153 gage and absolute pressure transmitters are tested following final assembly to verify compliance with specification. Additionally, a review of audit test data performed on final assemblies of model 1152 and model 1153 transmitters not tested foll6wing final assembly indicate Q.ALtuLATINJ Q0C'C0200--1369 FISHER ROSEMOUNT ATTACH HCT r.1 r,- % I At\K:7

conformiance to specification. Tcicrefore. the ambient temperature effect published in our specifications is considered +3a.

3. Overpressure Effect 1'estiniz of this variable is done at the module stagc. All (100%) range 3 through 8 sensor modules are tested for compliance to specifications. We do not test range 9 or 10 modules for overpressure for safety reasons. However, design similarity permits us to conclude that statcments made for ranges 3 through 8 would also apply to ranges 9 and 10. Therefore, the overpressure effect published in our specifications is considered +3a.

4. Static Pressure Effects All (100%) differential pressure sensor modules are tested for compliance with static pressure zero :..o.r,. Additionally. Niodels 1153 and 11 54 Rangcs 3, 6,7 and S art: 100%XV tcsted aftes final assembly for added assurance of specification compliance. Audit testing performed on ranges 4 and 5 have shown compliance to the specification. Therefore. static pressure effects published in our specifications arc considered +3a.

5. I'ower Supply Effcct 1'esting for conformance to this specilication is performed on all transmitters undergoing sample (audit) testing. This variable has historically exhibited extremely small performance errors and small standard deviation (essentially a mean error of zero with a standard deviation typically less than 10% of the specification). All transmitters tested were found in compliance with the specification. 'I'licrelore, power supply effect published in our specifications is considered +3o.

Should you have any further questions, please contact Jerry Edwards at (612) 828-3 i.

Sincerely.

Jerry L Edwards Manager, Sales, Marketing and Contracts Rosemotint Nuclear Instruments, Inc.

e ALOULA7IoAJ @Q4-200-1-1369 AT'TACR ME~fT

?A4 *Bz o7vbz FISHER-ROSEMOUNT

C(AlULATIOA) o,-OZCO- F- 136 REV- o ATTACHMESAr E

-LI ot EZ Telephone Call

_ubject Rosemount Model 710.U Trip/ . ob No. H/A calibration Unit Specifications rile No. N/A MST. Layer was contacted in order to clarify the specificatcns listed the Rosemount Trip/Calibration System Model 710DU Operations Manual. in clarification was required for the folloving:

- Master Trip Unit (MTU)

Analog Output Accuracy (Normal conditions)

Trip Output Repeatability (Normal Conditions)

- Slave Trip Unit (STU)

Trip Output Repeatability (Normal Conditions)

- Calibration Unit Accuracy The equation listed for the MTU Analog output Accuracy is as follows:

+/-0.15% (60 to 90'F) O.flS%/lOo'F According to Mr; Layer, the above equation is to be used in the following manner:

- For ambient temperatures in the range of 60 to 901F, Analog Output Accuracy - +/-0.15%(SPAN)

- For ambient temperatures above 90F, Analog Output Accuracy - (O.15% (SPAN) + (0.35%) (SpAN)/lOaF) (AT)

Where: AT - Ambient Temperature F

aALCULATwA - v Cr-Oz-J-136 9 . O ATTACfAi6JV E 1AGECZ O2 GE For example, suppose the ambient temperature at the trip unit location is 120-F. The associated trip unit analog output accuracy would be:

Analog Output Accuracy +/-(O. 15%(SPAN) + (0.351)(SPAN)/lO0F)((AT))

Analog Output Accuracy - +/-(0.15%(4 Vdc) + (0.35i)(4 VdC)/OO-F)(3o-F))

Analog Output Accuracy - +/-0.0102 Vdc The trip output repeatability for both the MTU and STU is calculated in the manner listed above. The equations are clarified below for ambient temperatures above 90-F:

MTU Trip Output Repeatability (MTU!T0):

MTUct +/-(0.13(SPAN) + (0.2%)(SPAN)/I0 0F) (AT))

S.J-ir output Repeatability (STU,.):

sTU~ -+/-(0.2%(SPAN) + (O.35%) (SPAN) /1O0F) (AT))

In addition, Xr. Layer stated that the trip setpoint repeata;4.t'"

equaticns listed above include reference accuracy, temperature _ .

drift. The equations are accurate for 6 months. Eased on calibration procedure DIS 1400-02, the trip units are calibrated every three Tuontk'3.

However, Mr. Layer stated that the errors would not be reduced by -

calibrating more frequently than. 6 2onths.

The MTU and STU trip setpoints are calibrated using the calibration unit su-olied with the Model 7100U. Hr. Layer stated that errors asscciated vQ-th the calibration unit are included in the repeatability error equations listed above. Therefore, no additional error evaluations are required for the calibration of the MTU and STU.