RS-04-110, 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)

ML042170075
Person / Time
Site:	Quad Cities
Issue date:	07/21/2004
From:	Simpson P Exelon Generation Co, Exelon Nuclear
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
RS-04-110 QDC-0200-1-1369
Download: ML042170075 (52)

Text

Exelon Generation www.exeloncorp.com Exelkn.

4300 Winfield Road Nuclear Warrenville, IL 60555 10 CFR 50.90 RS-04-1 10 July 21, 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)

References:

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

NRC, "Technical Specification Changes Related to Primary Containrrient Isolation Instrumentation (Main Steam Line Flow-High)," dated June 10, 2004 (2) Letter from P. R. Simpson (Exelon Generation Company, LLC) to U. S.

NRC, "Additional Information to Support Review of the Request for Technical Specification Changes Related to Primary Containment Isolation Instrumentation (Main Steam Line Flow-High)," dated July 19, 2004 In Reference 1, Exelon Generation Company, LLC (EGC) requested changes to the Technical Specifications (TS) of Facility Operating License Nos. DPR-29 and DPR-30 for Quad Cities Nuclear Power Station, Units I 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 setpoint and allowable value calculation for the proposed change. These calculations were originally provided in a letter from P. R. Simpson to the NRC dated July 19, 2004 (i.e., Reference 2). This letter supercedes the information provided in Reference 2 in its entirety.

July 21, 2004 U. S. Nuclear Regulatory Commission Page 2 EGC has reviewed the information supporting a finding of no significant hazards consideration that was previously submitted to the NRC in Attachment 1 of Reference 1. The bases for concluding that the proposed TS changes do not involve a significant hazards consideration are not affected by the supplemental information provided in the attachment to this letter.

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

I declare under penalty of perjury that the foregoing is true and correct. Executed on the 21st day of July 2004.

Respectfully, Patrick R. Simpson Manager - Licensing

Attachment:

Main Steam Line High Flow Differential Pressure Setpoint Analysis, QDC-0200-1-1 369 cc: Regional Administrator- NRC Region IlIl NRC Senior Resident Inspector - Quad Cities Nuclear Power Station

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

CC-AA-309-1 001 ExekonM ATTACHMENT i Design Analysis Cover Sheet Revision 0 Nuclear Last Page No. 33 Analysis No. QDC-0200-1-1369 Revision 0 EC/ECR 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 I & 2 DPT 1(2)-0261-2A (-2B, -2C, -2D) DPT 1(2)-0261-2J (-2K, -2L. -2M)

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

Code/Keyword 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. FromlTo Document No. From/To QCIS 0200-16 To OCIS 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 El No 3 Does this Design Analysis Contain Unverified Assumptions? Yes El No E ATI/AR#

Is a Supplemental Review Required? Yes E] No C If yes, complete Attachment 3 Preparer Patricia A. Ugorcak f Lt I- A *t .6 L 02-24-04 Print Name Sign Name ,4 4 Date Reviewer Richard H. Low 'f 2 02-24-04 Print Name Sign Name Date Method of Review ED Detailed Review E Alternate Calculations El Testing Review Notes:e Approver I. A. Khan 02-24-04 Print Name Sign Name Date (For External Analyses Only)

Exelon Reviewer jS' k ..k710oq a Print Name Sibn Nae Date Approver 9 P7 lb 'I Print Name Sign Na# 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 I ATTACHMENT 1 General Review Questions Page 1 of I DESIGNANALYSISNO. Q-DC-o)°O-I- 139 - REV: 0 EC- 315 3 as- EC- 3qS3Zq Yes No N/A

1. Does the design analysis conform to design requirements? El E]l

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

0.

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

4. Is the analysis method appropriate? El El E]

5. Are the methods used and recommendations given conservative relative to El-,

the design and safety limits? El El

6. Are assumptions/Engineering Judgments explained and appropriate? al

7. Have appropriately verified Computer Program and versions been identified, when applicable? O1. El

8. Does the Computer Program conform with the NRC SER or similar document when applicable? El El1 El"

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

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

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

12. Are the recommendationslresults/conclusions reasonable based on previous experience?

El El

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

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

15. Has the effect on plant drawings, procedures, databases, and/or plant B.- El simulator been addressed? #A CC-El El

16. Has the effect on other systems been addressed? as EC- B-"

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

18. When applicable, are the analysis results consistent with the proposed license amendment? la, El El1

19. Have other documents that have used the calculation as input been reviewed and revised as appropriate? El El 211"

CC-AA-309 Revision 3 Page 15 of 15 ATTACHMENT 2 Owners Acceptance Review Checklist for External Design Analysis Page I of 1 DESIGNANALYSIS NO. Q-0 ocP 00 -(7 - REV:

rCC3qS3;3 a-c -3453, Yes No N/A

1. Do assumptions have sufficient rationale? EK El El

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

2. licensing basis?

3. Do the design inputs have sufficient rationale? Z '[El El

4. Are design Inputs correct and reasonable? 0[3 l 0

5. Are design inputs compatible with the way the plant Is operated and with the Ef E D licensing basis?

6. Are Engineering Judgments clearly documented and justified? l Ela 7 Are Engineering Judgments compatible with the way the plant Is operated El El and with the licensing basis?

8. Do the results and conclusions satisfy the purpose and objective of the design E E El analysis?

Are the results and conclusions compatible with the way the plant is operated E 0/ E and with the licensing basis?

10. Does the design analysis Include the applicable design basis documentation? B E l Have any limitations on the use of the results been identified and transmitted E E E to the appropriate organizations? E. E C..

12. Are there any unverified assumptions? El 0Ed

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

D El EXELON REVIEWER: J o'. %LIAY ( Do 7 Print ISig

CC-AA-309-1001 Revision 0 Nuclear DESIGN ANALYSIS TABLE OF CONTENTS ANALYSIS NO. QDC-0200-I-1369 REV. NO. 0 PAGE NO.2 SECTION: 1 PAGE NO. SUB-PAGE

_ _ _ _ _ __ _ _ __ _ _ J _ _ _ _N O .,

DESIGN ANALYSIS COVERSHEET I 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. 1, dated May 5, Al-A3 1994, "Main Steam High Flow Trip Setting" B BIF Vendor Information BI-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- El-E2 16-93, Rosemount Model 71 ODU Trip/Calibration Unit Specifications a i

CC-AA-309-1001 ExeIon.. Revision 0 Nuclear Anal]sis No. QDC-0200-1-1369 Revision 0 Page 3 of 33 1.0 PURPOSE The purpose of this calculation is to determnine 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 heat 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 2-0261-IA FE 1-0261-lB FE 2-0261-lB FE 1-0261-IC FE 2-0261-IC FE 1-0261-ID FE 2-0261-1D 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 Exelomm Revision 0 Nuclear Analysis No. QDC-0200-1-1369 Revision 0 Page 4 of 33 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 1 Setpoint as defined in Reference 5.2, Appendix D, Graded Approach to Determination of Instrument Channel Uncertainty. As a Level I, this means that the random errors (a) to a I0 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= 2 +Ee 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 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.

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 Revision 0 Nuclear l 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.

1. 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 Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 rPage 6 of 33 l 3.0 ASSUMPTIONS / ENGINFERING 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 71 ODU 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 Exelknm Revision 0 Nuclear I Analysis No. QDC-0200-I-1369 I Revision 0 l 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 3o 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 .1Isolation 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 w/Throat Taps EPNs: FE 1(2)-0261-1A, (-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 2-0261-1A, 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-IA 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. II53DB7PA [Ref. 5.131 URL 300 psid [Ref. 5.131 Output 4-20 mA [Ref. 5.131 Reference Accuracy [3co] +/-0.25% calibrated span Drift [2o] +/-0.2% upper range limit (URL) for 30 months Normal Temperature Range 400 F to 200OF Humidity Limits 0-100%RH (NEMA 4X)

Temperature Effect [3a] +/-(0.75% URL + 0.5% span) / 1000 F Static Pressure Zero Effect [3o] +/-0.5% URIJi 000 psi, correctable through re-zeroing at line pressure Static Pressure Span Effect [3oJ +/-0.5% Input Reading / 1000 psi High Line Pressure Correction +1.25% of input/1OOpsi Overpressure Limit 2000 psig Power Supply Effect (3a) Less than 0.005% output span per volt Relative Humidity 0-100% RH Radiation Effect [2o] +/-8.0% URL during/after exposure to 2.2 x 107 rads TID Seismic Effect [2a] :0.5% URL during/after ZPA of 4g

CC-AA-309-1 001 Exelknm Revision 0 Nuclear I Analysis No. QDC-0200-I-1369 I . Revision 0 l 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 -2I-1, 20-1 and 2Q-1 Manufacturer Rosemount Model No. 710DUO1T23032 Input Signal 4-20 mA Output Signal Bi-stable: 24Vdc for Logic Level 1, <lVdc for Logic Level 0 Repeatability (Normal) [2ca] +0.13%(Span) (60 IF to 90 0F)

_0.20%(Spanyl00 IF (Above 90 0F)

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'F (normal) 160'F (24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, once/year) 1851F (Accident for 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />) 150 0F (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) 12 x IO' 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 -l OB, -I 0C 2-2202-9B, -1OB 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 650F to 104IF Ambient Pressure 14.7 psia Humidity 20 to 90% RH Radiation <1.OE04 RADs (40-Yrs)

CC-AA-309-1001 Revision 0 Nuclear Analy sis No. QDC-0200-1-1369 l Revision 0 l Page 9 of 33 11 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' / Cable G-26 F-26 Spreading Room EQ Zone 18a Normal Operating Conditions Ambient Temperature Range 70'F to 80'F Ambient Pressure 14.7 psia Humidit - 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 4-3.0 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 +0.08 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. 5.11)

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

4.6 Calibration Instrument Data - Calculation NED-J-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 Revision 0 Nuclear l Analysis No. QDC-0200-1-1369 Revision 0 l Pae 10 Of 33 4.6.1 Pressure Sensing M&TE, for transmitter input Calibration Instrument MTE Error (1 a) Evaluation Parameters MTE2 - Heise CMM (0 - 400 psig) + 1.744484 psig 104 OF MTE3 - Druck DPI 601 (0 - 500 psig) 4 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 (2cr per Section 3.1)

Readout Assembly Resolution: +0.01 mA over normal temperature range of 40'F to 104'F, (2cr 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 IF (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, Fa = 1.0092 (Reference 5.6).

4.13 Upstream specific volume (ft3 /lbm) at 1020 psia and 546.99 'F, v = 0.4362 ft3/Abm(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 informnation. (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 Mlbthr)* (1000 klb/Mlb)/4 = 2928.25 1;Ib/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 Exele nm SRevision 0 Nuclear

, Analysis No. 9DC-0200-1-1369 Revision 0 1 age 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/fl3 ). 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 2a 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 Exe l n. SRevision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 Page 12 of 33

5.0 REFERENCES

5.1 ANSIIISA-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," ComEd 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 1 Division I Main Steam Line High Flow Switch Calibration and Functional Test 5.4.3 QCIS 0200-62, Rev. 1, Unit 1 Division II Main Steam Line High Flow Indicator and Switch Calibration and Functional Test 5.4.4 QCIS 0200-65, Rev. 2, Unit 1 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 11 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 1 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 71ODU 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 1(2)-0261-2A-1 through 2S (excluding 1, 1, -2Q-1), as revised per ECs 345323 Rev. 0 and 345324 Rev. 0)

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

FE 2-0261-1A 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 Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 l T Fage 13 of 33 5.10 Quad Cities UFSAR, Rev. 7, January 2003 5.10.1 Table 4.1-3, Thernal 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 I 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 1 5.20.2 M-13 Sh. 1, Diagram of Main SteamPiping 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 71ODU Trip/Calibration Unit Specifications (Attachment E)

CC-AA-309-1001 Exelnm. Revision 0 Nuclear E .AnalysisNo. QDC-0200-1-1369 Revision 0 -T PageM1 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*(CYdF.)*[(pAP)/(1 _ p4)]% Eq. 1 Where: W = mass steam flow in lb/hr C = discharge coefficient = 0.995 Y = gas expansion factor (ratio) 4 )(1 4 2r &k)) Y' y = (rlA(k/(k-l ))[(I _r[(k"k')I(I r)] [(JI- _p 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 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 1 and 2: (9.970"117.938")

Solving for AP: AP = [W/(1890.07*CYd2 F,)12 [(1-W 4 )/p] Eq.3 Initial value at Y=l: AP = [W/(1890.07*Cd 2 Fa)] 2 [(1 I 4)/p] Eq. 4

CC-AA-309-1001 ExeIkn. Revision 0 Nuclear Analsis No. DC-02004-1369 Revision 0 _ Pae 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 k D F B kt(k-l) 21k 0.995 1.256 9.97 1.0092 0.555803 4.906250 1.592357 W JStatic P ip AP(Y=i rl Yl API r2 JY2 AP2 292825011020 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 1r4 Y4 AP4 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

=

10.72513 0.80680 286.18167 = .=.

r5 Y5 AP5 r6 - Y6 AP6 2928250 1020 2.293 0.89113 0.92509 111.05792 0.89112 0.92509 111.05792 4099550 1020 2.293 0.71943 0.80262 289.17027 0.71650 0.80047 290.72573

_r7 Y7 IAP7 lr8 IY8 kAP8 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 lrIO Y10 AP10 l 4099550 1020 2.293 0.71375 0.79845 292.19861 0.71353 0.79829 292.31575 rl YII APIl r12 Y12 AP12 1 4099550 1020 2.293 0.71342 10.79821. 292.37434 0.71336 0.79816 1292.41098 1 r13 Y13 AP13 rI4 Y14 aP14 I4 4099550 1020 2.293 0.71332 0.79813 292.43296 0.71330 0.79812 1292.44029 1 l rI5 Y15 AP15 lr6 Y16 1AP16 _

4099550 1020 12.293 0.71329 0.79811 292.44762 0.71329 0.79811 292.44762 _ 7 I r17 Y17 AP17 r18 Y18 AP18 _

4099550 1020 12.293 0.71329 10.79811 292.44762 7 1= 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-309-1001 xelon.. MRevision 0 Nuclear Analysis No. QDC-0200-1-1369 Revision 0 Page 16 of 33 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 (a,)

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 + U 1 S + P2+ UDSL )

Base Uncertainty (UJ)

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:

UE = 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 Strai ht Run Uncertainty (U.dsh Per Sections 4.10 & 4.11, the inner pipe diameter is 17.93 8" and the nozzle throat diameter is 9.970". This produces a beta ratio P = 9.970/17.938 = 0.556. Conservatively approximating with an upstream straight pipe run ratio of I for a 0.5 P ratio curve in Figure 4.5 of Reference 5.15, means that ULNs = 1.25% of flow.

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

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 (USA 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 p = 9.970"/17.938" = 0.556. Conservatively approximating with a downstream straight pipe run ratio of 0.8 for up to a 0.75 P ratio curve in Figure 4.9 of Reference 5.15, means that ULNs = 1.05% of flow.

Therefore: ULNS = 1.05% flow

CC-AA-309-1001 Revision 0 Nudear l Anal sis No. QDC-0200-I-1369 I Revision 0 l Page 17 of 33 i 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 + ULNS+ UI2 + UDSL2) 0.5 = 4((3 .0)2 + (1.25)2 + (0.18)2 + (1.05)2)0.5

=i3.42 % 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 int6 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 [2cr]

At 4099.55 1db/hr (140% flow), and dividing by 2 to get a lc value:

UO,4 = 3.42 % * (4099.55 klb/hr)/ = 70.102 klb/hr [la]

The differential pressure must be determined for flows of 4099.55 +70.102 klb/hr, which equals 4029.448 klbfhr and 4169.652 1db/hr.

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

From Attachment to GE SIL 438, Rev. 1: W = 1890.07*(CYd2 F,)*[(pAP)/(I - p4)]2 Eq. 1 Where: W = mass steam flow in lb/hr C = discharge coefficient = 0.995 Y = gas expansion factor (ratio)

-I 4 )/(l _34r 2"k)]} "

Y = (rllk(k/(kI))[( Il -_(Yk')/(I-r)][(l 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 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) f = ratio of throat to pipe diameters Units I and 2: (9.970"/17.938")

Solving for AP: AP= [W/(1 890.07*CYd2 F8 )]2[(l -p4 )/p] Eq. 3 Initial value at Y=1: AP = [W/(1890.07*CdF,)] 2 [(l-B4)fp1 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-309-1001 Exelkn. Revision 0 Nuclear I Analysis No. QDC-0200-1-1369 Revision 0 Page 18 of 33 Units I & 2 Operating dPs C K D F I__ _kl(k-1) 12/k 0.995 1.256 9.970 11.0092 j0.555803 4.906250 1.592357

__ Static P P APY=1 JRi Y API r2 Y2 AP2 4029448 1020 2.293 179.96677 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 2.293 0.72222 0.80467 297.62213 0.70821 0.79437 305.39025 Ir5 Y5 lAP5 .r6 Y6 (AP6 1 402944811020 2.293 10.73644 0.81507 270.89595 10.73442 10.81359 1271.882421 416965211020 2.293 10.70060 0.78875 1309.75769 10.69632 10.78558 1312.26262 1 f r7 Y7 JAP7 jr8 jY8 AP8 4029448 1020 2.293 0.73345 0.81289 272.35087 10.73299 10.81255 272.57884 _

416965211020 2.293 0.69386 0.78376 313.71454 10.69244 10.78270 314.56483 _--

I Ir Y9 aP r10 lY10 laPI01 4029448 11020 2.293 10.73277 10.81239 j272.68622 j 0.73266 0.81231 1272.73993 I 416965211020 2.293 10.69160 10.78208 1315.06378 10.69111 0.78172 1315.35403 1 I I Iri1 APl Ir12 IY12 ; IAP12 4029448 11020 2.293 10.73261 10.81227 1272.76679 10.73258 10.81225 1272.78023 4169652 11020 2.293 10.69083 10.78151 1315.52353 10.69066 10.78138 1315.62853

- rl3 [Y13 1AP13 r44 ]Y14 1^P4 1-4029448 1020 2.293 J0.73257 0.81224 272.78694 0.73256 0.81224 272.78694 4169652 1020 2.293 10.69056 0.78131 315.68509 0.69050 0.78126 315.72550 1rl5 Y15 AP15 r16 Y16 AP1I6 4029448 1020 2.293 0.73256 0.81224 272.78694 1= 272.79 4169652 1020 2.293 0.69047 0.78124 315.74166 0.69045 0.78123 315.74975

- Ir17 Y17 AP17 r18 Y18 AP18 4169652 1020 2.293 0.69044 0.78122 315.75783 0.69043 0.78121 315.76591 rI19 Y19 AP19 jr20 Y20 aP20 - _I _ I 416965211020 12.293 10.69043 10.78121 1315.76591 10.69043 10.78121 1315.76591 1=315.77]

From Section 6.0,-the differential pressure at 140% flow (4099.55 k1b/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: FEH = 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.

RA1I= 23.32 psid [Ia]

CC-AA-309-1001 ExeIsn M Revision 0 Nuclear r

Analysis No. QDC-0200-I-1369 Revision 0 l Page 19 of 33 6.1.1.3 Calibration Error and Setting Tolerance (CALI &ST1)

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

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

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

Therefore, alINn =0 [1a]

6.1.1.6 Determination of Total Random Errors (Icrl)

ECr1 = [RA12 + CAL12 + ST12 + CDl 2 + GINn2 ]0 -5 Because all these values are zero except for RAI, this simplifies to: a1=RAI at 140% flow: Ecl = RAl = 1 23.32 psid [IC]

CC-AA-309-1001 Revision 0 Nuclear l Analysis No. QDC-0200-1-1369 I Revision 0 l Page 20 of 33 1

• 6.1.2 Non-Random Errors (tel)

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: cIT = 0; per Design Input 4.19, no ambient effects inside the pipe.

Radiation Errors: elR = 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: e ISP = 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: eIV =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=0 6.1.2.2 Non-Random Input Errors (e I rN)

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 (EeI)

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+elS + elSP +elP+elV +elp+ e1 ]

Because all of these errors are zero, Eel = 0

CC-AA-309-1 001 Exe 1 nn >Revision 0 Nuclear Analysis No. QDC-0200-1-1369 Revision 0 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 (cr2) 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)13 = 0.01333 mA [Ia]

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=+/-1.74448psid [1a]

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) * (:L.74448 psid) = L0.09304 mA [la]

6.2.1.2.3 Total Calibration Error (CAL2)

The total calibration error associated with the transmitter is:

CAL2 = +/-[(STD2)2 + (MTE2') 2 ]V = 41(0)2 + (0.09304 mA) 2]A.. =+/-0.09304 mA [la]

CC-AA-309-1001 Exe o n 5Revision 0 Nuclear I Analysis No. QDC-02004I-1369 IRevision 0 1Page 22 of 33 6.2.1.3 Transmitter Setting Tolerance (ST2)

From Section 4.5 and 2.M.3.F, the setting tolerance for the string calibration to the MTU is 13.0 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)*(l6 mA /300 psid) /3 = 4 0.05333 mA[la]

6.2.1.4 Drif 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 (SI) for the device is 24 months with an additional 25% late factor. Therefore, the expected drift error converted to la is:

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

= i(0.2%(300 psid)/30 months)(24 months)(1.25) /2 = d0.30000 psid [IC1]

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

DR2' =DR2*(16 mAI300 psid)= (b0.30000 psid)*(16 mA/ 300psid)

=d0.01600mA [IcY]

6.2.1.5 Temperature Error (e2T)

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 IF. 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 =I:((0.75%(URL)+0.5%(Span))/100 O]F)( AT) [3cr]

= ((0.75%(300 psid) + 0.5%(300 psid))/100 °F)(1 04 'F - 65 'F) / 3

= 40.48750 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 mA/300 psid) = (+/-0.48750 psid)*(16 mA/300 psid)

= +/-0.02600 nA [ICY]

6.2.1.6 Static Pressure Error (el SP)

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)/1000 psi)*(Static Pressure)

= (:0.5%(300 psid)/1000 psi)*(1005 psi)

=A1.50750 psid [3a]

CC-AA-309-1001 Exe 1 nn >Revision 0 Nuclear l Analysis No. QDC-0200-I-1369 l Revision 0 l Page 23 of 33 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)/l 000 psi)*(Static Pressure)

= (+/-0.5%(300 psid)Il000 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] =d:[1.50750 psid + 1.50750 psid]

= 43.01500 psid [3(1 This is converted to mA by multiplying by the ratio of the spans, as in Step 62.1.2.2, and taken at a I a value:

e2SP' = (e2SP)*(16 mA/300 psid)/3 = (+/-3.015 psid / 3)*(16 rnAJ300 psid) d0.05360 mn [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=OmA [1a]

6.2.1.8 Radiation Error (e2R)

Per Section 4.4.1, the radiation at the transmitter location is *1.OE04 rads, which is considered a mild environment. Therefore, the radiation effect is negligible per Section 2.1.3.B & D, so:

e2R= OmA [ICY)

-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, Ecy I= 23.32 psid, [1c(]. Therefore:

o2in = EI = +/- 23.32 psid [1a]

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

CC-AA-309-1001 Revision 0 Nuclear I Analy'sis No. QDC-0200-1-1369 IRevision 0 1 Page 24 of 33 c2in' (a2in)*(16 mA/300 psid) = (+/-23.32 psid)*(16 mA/300 psid)

=+/-1.24373 mA [1a]

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.

+/-(RA2)

[= + (CAL2)2 + (ST2) 2 + (DR2)2 + (e2r)2 + (e2SP') 2 + (e2V)2 + (e2R) 2 +

(e2S) 2 + (a2in)l"2

= +/-[(0.01333 MA)2 + (0.09304 mA)2 + (0.05333 mA) 2 + (0.01600 rnA)2 + (0.02600 MA)2 + (0.05360 mA)2 + (0 mA) 2 + (0 mA)2 + (0 mA) 2 + (1.24373 mA)2]"'

= 1.24994 mA [ICY]

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 (c2in) 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

= 41(0.01333 MA) 2 + (0.09304 MA) 2 + (0.05333 mA)2 + (0.01600 mA)2 ]i/

= L0.10924 mA [1a]

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, Zel = 0 e2in = Eel = 0

CC-AA-309-1001 exekr n~ 5Revision 0 Nuclear I Analy'sis No. QDC-0200-I-1369 IRevision 0 1 Page 25 of 33 1 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:

Ee2 = e2H + e2AP + e2P + e2in Te2 =0+0+0+0 Ee2=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/1 000 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 Exe on SRevision 0 Nuclear Analysis No. QDC-0200-I-1369 l Revision 0 l Page 26 of 33 l 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 (a3) 6.3.1.1 MTU Repeatability (RPT3)

Per Section 4.3.3, the repeatability is *0.13% of span for temperatures between 600 F and 90'F. Per Section 4.4.2, the ambient temperature varies from 700 F to 80F. Thus:

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

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

= +/-0.01040 rnA [IC]

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 MTU 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 = 0 [la]

6.3.1.3 MTU Setting Tolerance (ST3)

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

ST3 = 40.08 mA/3 = 10.02667 mA [IY]

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 [=+/-]

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 Revision 0 Nuclear Analysis No. QDC-0200-1-1369 I Revision 0 Page 27 of 33 l 6.3.1.6 Radiation Error (e3R)

From Section 4.4.2, the radiation level within the MTU environment during normal operating conditions is < 1 x 1OE4 RADS TID. From Section 4.3.3, the accuracy of the MTU will remain within its stated repeatability within radiation levels. I x IOE5 RADS TID. Therefore:

e3R = 0 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 MITU 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 = 0 6.3.1.10 Random Input Errors (a3in)

The random error present at the input to the MTU during normal operating conditions, o3in, is the random error present at the output of the transmitter and was calculated in Section 6.2.1.11 a3in = cr2 = 1.24994 mA [1a]

The random error present at the input to the MTU due to the transmitter, 03inAV, used for calculating the allowable value, was calculated in Section 6.2.1.11 as c2AV.

a3inAV = a2AV 0.10924 mA. [Ia 6.3.1.11 Calculation of Total Random Error (a3)

The total random error is the SRSS of the random errors from Sections 6.3.1.1 through 6.3.1.10. Therefore,

=4 [(RPT3) + (CAL3) 2 + (ST3) 2 + (DR3) 2 + (e3T) 2 + (e3R) 2 + (e3S)2 + (e3SP)2 +

(e3V) 2 + (a3in) 2l'A

= 4 [(0.01040 MA)2 + (0 MA) 2 + (0.02667 MA) 2 + (0 mA)2 + (0 MA) 2 + (0 mA) 2 + (0 mA) 2 + (0 mA) 2 + (0 mA)2 + (1.24994 mA) 2]VZ

=- 1.25027 mA [Il]

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

u3p (+/- 1.25027 mA)*(300 psid/I6 mA) 23.44252 psid [la]

CC-AA-309-1001 Revision 0 Nuclear Analysis No. DC-0200-I-1369 I Revision 0 Page 28 of 33 Per Section 2.1.31.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 = +[(RPT3)2 + (CAL3)2 + (ST3) 2 + (DR3)2 ] '

= +/-[(O.0 1040 MA) 2 +(O mA) 2 +(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 o3inAV, since CAL and ST are included in a3 inAV. Thus, a3AVSTRING=^ = +/-[(RPT3) 2 + (DR3) 2 + (a3inAV)2 ]

= :[(0.01040 mA) 2 + (0 MA) 2 + (0.10924 mA)21J

= t0.10973mA [la]

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:

a3AVSTRINGp= (+/-0.10973 mA)*(300 psid/16 mA) =+/-2.05744 psid [la]

6.3.2 MTIJ 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 (e3in)

The non-random error present at the input to the MTU during normal operating conditions, Ze2, is due to the transmitter and was calculated in Section 6.2.2.5:

e3in = 1e2 = 0 6.3.2.5 MTU Total Non-Random Error (Oe3)

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

Ee3 =e3H+e3P+e3p+e3in=0+0+0+0

= 0 psid

CC-AA-309-1001 Exekn5 . Revision 0 Nuclear I Analysis No. QDC-0200-1-1369 I Revision 0 Page 29 of 33 l 6.4 TOTAL ERROR AND SETPOINT ANALYSIS Per Section 2.1.2, total error is: TE = 2o + le. 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:

SPc, ,A = (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 mrA) * [(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 1.

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 Exelem Sm Revision 0 Nuclear I Analysis No. QDC-0200-1-1369 I Revision 0 Page 30 of 33 auSTRING = a3AVSTRINGp = +/- 2.05744 psid [I a) [6.3.1.11]

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

In psid: oup (2a) = 2 * (+/- 2.05744 psid) = +/- 4.11488 psid = i 4.1 psid Therefore, the AV is calculated as: AV 5 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 YihA 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 1 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(2ar) - ST)] + ST (where ST is 2c)

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

ST2(2a) = 2*(ST2(3a)13) = 2*(+/- 3.0 psid)/3 = i 2.0 psid aup(2a) = 4.1 psid [6.4.3]

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 3o 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) PASS Therefore, the ET is acceptable as defined at a value of 3.4 psid.

E xeI nl CC-AA-309-1 001 Revision 0 Nuclear I Analysis No. QDC-0200-I-1369 l Revision 0 lT 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 = i [0.7 * (aum(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 [la] [6.3.1.11]

Thus, the au to 2a is calculated as:

auti(2a) =2 * (3AV (la)) = 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 a)) = 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 2cr)

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

ST2(2a) = 2*(ST2(3a)/3) = 2*(+/- 0.08 mA)/3 = i 0.05333 mA For the calibration of the transmitter alone, au,,,, is conservatively based on the S2AV from 6.2.1.11, where a2AV = 4:0. 10924 mA (I a).

au,4(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 3ca value of the transmitter ST, from 4.5.

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

CC-AA-309-1001

• Exelkn.s Revision 0 Nuclear Analysis No. QDC-0200-I-1369 F 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 % < 292.45 psid Allowable Value (AV) <= 134 % < 248.1 psid < 17.23 mA Setpoint (SPc) 133 % 1 244.0 psid 1 17.01 mA 1 Rated Flow 100 % 111.o6 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-I 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 L.d and Table 3.3.7.1-1 Itemn 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 IF0.16 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 12.10mA 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 Revision 0 Nuclear Analysis No. QDC-0200-I-1369 Revision 0 l Pae 33 of 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 nA 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)

• 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]

-~- - Y

, 'i * -

ga~y 1. ~ ? SIL GEcuclearEnergy SeMces Information Lerrar Main steam line high flow trip setting SIL No. 438 The original SIL 438 was written becuse a re- steam. lines carrying approximately 133 To of it Revision I view of the MSL high flow crio secoint for an normal flow at 100% power.

operting BWR disclosed an inconsistency be-34any plant technical specfications spue& 4 3set-

.%fy, 294tc eer:. tne ac-ua! sectinc and chat speAecd in -. pcint for thu MS.' *-.igh sow eio based on an plant tcchnical specificadons. The difference ws uoperaa.nalvtc:3 liL.mitoof euivalent to 1-0% NBSRE a-bu:ed to the use o. design stea-. flow ca..ci-steam flow. T1he acual serpoint is then calculate dons rather than rated conditions in the orininal as a maximum pressure drop across the diferen-semoint calculation. The original SiL 438 in-dal pressur: sersing device.

formed BWR owners of this potential inconsi-tency and provided a method for determining .An inconsistency was discovered in one instance the proper setmoint for the MSL hizh flow t. in which dhe calculated di-eren.tial pressure set-point was based on the design stam Qow condi-This Revision 1 to SE 438 correc an error in the equation for calculating the M1SL high flow dons for che turbine (105% NTBR steam flow) rather than the rmted. licensed power conditions trip serpoint. Using the uncorrect-d equation for the nuclear boiler. This resulted in a differ-found in the original SE. 438 could result in a' ential prssure serpoint that corresponded to non-conservatism of aporoxirname!y 3% steC.

aoproxinare!y 147 % NBR steam flow, which is flow when calculating the analytic -'mitor c.'.

inconsistent vuith the plant technical specifica-serpoint.

cors.

Discussion The safeit significanct of this potential inconsis-The ?.Main Steam tine (?MSL) high flow sensor, tency is a slight i^ -ase ir. the maximum detect-detec: and isolate breass in the main steam lines able stean line break size as detected by the outside the reactor conainment. The high Cow steam line differential pressure sensors. There trio initiates reactor isolation by dosing the main are additional lealage detection monitors which Stean isolation valves (MSTV) to minimize poten- would also initiate steam line isolation. Without tial release of radioactive materials to the cnmi reliance on these additional monitors. a conser-ronment. vative evaluation of the high setDoint demon-srates thaz the setpoint difference results in less The trip signal for the MSL high flow isolation is than a ten oercenc increase in released radioac-cken eorn differential pressure instruments in tive material. which is significantly less than the the flow limiters (vencuris) in each steam line.

IOCFRIOO limits. Because there is no significant The vencuris also limit the maxirnum flow loss change in the margin to allowable limits. the from a steam line break to approximately 200 %o higher setpoint is not a safety concern.

of rated steam flow for that steam line. The maximum setpoint for the MSL high flow t.ip Recommended action must be less than the maximum flow (choke GcE Nuclear Energy recommends that owners of flow) calculated (or each steam line, and the GE BWRs verify that the proper instrument trip minimum setpoint should be susiciently above secpoint has been escablished. The following 100 % of rated steam flow for each steam line to method is recommended for determining prevent spurious trips. A typical serpoint whether there is an inconsistency becwcn plant (analytical limit) is 140 % Nuclear Boiler Rated technical soccifications and actual trio semoints.

(NBR) steam flow. This setpoinc permits on-line The calculated differential pressure at the Bow testing of the MSIVs. because closing one valve rate corresponding to the MSL high flow trip would result in each of the remaining three Calculation QDC-OZOO-I-1363, Rev. 0 Artrnrhme~nt A Pam-p A I m-FA2

SIL No. 438 Revision I - page 2 scpoinc allowed by the technical specificaions rmy be checked agaiins the ac:uaJ trip SCepoinL The equation for clculating this flow rate is shown in Attachment 1.

I o rtceive additonal information on this subject Technical source dadon. plecse concactyourlocal GE Nuclear F.n- "VI. DriscoU cr~V Service Represencandve.

Is:u-29 y This SU s only to GE BWR. The condi-c.- LL-v dons under which GC NuclearEnergy issues S s are scated in SR.L No. 001 Revision 3. the provi-sions of which are incorporated into this S1L by referencc. R. M. Fair.ield. ,gram Manager Service Informadon Communications Produc refarence GE Nuclear Energy B21-Nuclear Boiler 175 Curtner Avenue. SanJose. CA95125 Calculation QDC-OtOO-I. 13Mg. Rev. O Attachment A, Page A2 of A3

Attachment I to SIL No.438 RevWsion I pageAI Calculationof main steam line high flow trip setpoint The equatonl for calculating the main steam line high flow rrip secpoint is:

Y= 1890.07 CYdF (p p)If where:

A r k X__ _ _

~ kX F 1-r l(BVrz`k)J W = steam fiow rate at desired analytic limit or trip setpoint (lbm / hr)

C = coe icient of discharge (0.995 for a venturi tube with a machined entance cone) (ratio)

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

F, = area thermal expansion factor (ratio)

(Approximately 1.0092 for 300 series stainless steel primary elementtherrnal expansion from 680 F to 5500F) p = uDstreZM fluid density Obm/ f;'). (rated condition of dry, saturated seamrn) r = ratio of throat static pressure to inlet satic pressure 'p (absolute pressures) k = ratio of speciflc heats of fluid, C7 (isentropic exponent for ideal gas, approximately l.'SS for dry, saturated steam at 1050 psia and 550 0 F)

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

Y = expansion factor for a gas (ratio) lAmnericn Sociccy of Mcchanical Enginecrs. Rcpon of ASME Rcscarch Comnuttec on Fluid Meters'. SLvXh Editionr 1971. P. 233, and May 1974 Errata.

Calculation QDC-CZoO-1. 1369, Rev. 0 Attachment A, Page A3 of A3

YFT7.7~ii3Y

-i~~:-~u ~7 s n 7 i

A SHOR A;-IICR]I I'?D.

he High Street F'mrnae r,.- cerfectec the ne cssa5 *n a:ernnc.

-. j _zrvany, was. litle rmcrz than a z1 to enaiae use cfr e ElF Vn:uri .ub'e as a -'cv

,b-lacksmith shcp w.hen it ec, n mneasurement toct. -rnur"_ces anr -- e*ters

• rcducirng ircn cIows in h.ave een '.vo cr -. s .os; irccrn--r:

3 4rcvideence 2.naround 1 -'

.cia 'o The nenivync r Sam!

^crtie Euilider's Ircr; Fcundri ir. iS, AA

-e -.ewowners acCed procuc;s ,vr.:c-ne zrcmise cr grcz;- and-r icr-c -.;re

-flec:-d .heir own areas c exse-:se.

-;,Fs stated curpose at inc-r:cra:icr.

as rh"ma-ufat

,2cre cf ir::r. 5cr.-s _ -v@:szs a.-- *_.er castings .cr budlcers ar c_..r ses.:' Ex'amples cf the crnament--l ir-n.wcrX

-nwervf -:act 4umztf -'CrE331 .- W-VAW C.!

r: :uc-d /YEF durIng ghe micd i,CC's can s;i! '-- seen on h'le Ccngress, ofibrary pr:cL'cts eversinca.- . ntmuigdecicaticn :-

-uiiding in Washington. Other prodc-:s crc- ucgrading 6.ese z r-ouc:s-d-s -- I, s r-sear:

cuccd _v IF during tha-,; ercc irc:tce- arncdev cc~e; -. ._ imr shrsal ;ient.urt cylinders ,5cr bridge piers and preiatricated TceJn 1c7C. time rf its it intrcduc:icn, iig--cuses whic.. were irstalled arcund .t'e '*e UVT W2as the r-s~it of :hcusandcs c." hrcus wovrld. of desicn -rncinreerrnc and -iccrcus h'-;&:_iic

,.-e cemand ,5cr EIFs architecturai r-:n :esring. Tlhe UT rea-:v ir.cr-ased the r-i;a-cec'ir;d as szeel came into imore wicescread bilitty and accuraacy co ficwv mneasureentert. At use anc cecora!ive iron fell cut of .ashicn. trhe same time, the L\i7 r rduce-d costs of bct..

'ess rescurceful ..r...s might have cided, b-ut lead-in picing anc surrcinc structures by ElF resconded by enterirn Intorarkets eliminating the preicus reoutem:en: tcr icrc

-eeingcproduccs which could 'ce mr..ao- rnr.s c straight pice in-- a 'Venturi.

turec with methods and materials similar to thcse ElF ha~d been using. Crne cf the Icgical More than 160 ears ^av e passec ircce transiticns EIF made at that time included tree .igh . ra-- ocany =treet pr::uC changing production from ircn archirect.-ral its first iron -Icw. its suc-cclurmns to casscr, El.-, has success- -7 fully designed. marnfac- '.

l water pipes. tured. and m.arke.e- 2a _ .$ - Vl ;,

, In 1287 steadily evolving cr:cuct r  :

.M'TI_ Clemens Her- line 'cr over 13 decades. . .

I sc.el intrcduced Tccay EIF, a Unit of '3erErl  : ..  : *.i l '-the Herschel Signal, is recognriec wcr!d- *.. ' _'* '

-

• , Sandardcen- wide as a leacer in auto-

turi, by .ar the madiC fIcw control, :n cCn- .r most accurate trIled feeding and weighing

• i Ilcwmeter avail- co iicuids ard solids, and r. nwastewarerand able ovfer the water treatment sys;-r.ms.

ensuing E0 years, In 1893

'he Chiei Err A rF~lac!.ICUS at Plum lWanIMofrr gineer

'IF. at

39 SJn O .^IdoJ

` ar ,7 ;n N. Cot.nner,40

.332 Jr71 00-tratonifftar Q.rlf 70 Tqr1 F. N\.Ccrnnet, 1233 D-10I PAGOE2 SERIES :aQ U'V 4.%j  :.,A", It 'x"Wii, 'I.. )

AEttachmerlt 13. Patze St CS

Km

. GENL SIG/LEEDS & NORTHRUP 21E D-l- 3IN19 aO Os94 5 M F-&-

THE RIGHT FLOWMETER FOR EACH APPLICATION Calculation QDCO0200-l- l369, Rev. 0 Attachment B Page 62 of B4 BIF has the experience and ex- * *~, ~*.

pertise to approach any applica-tion with the confidence that Standard Sfzes 180 we have solved the problem

_efcr-. We can handle the jcb ,;. a economically and reliably. W'ie i kna .S a se lorcstoril hamrar. a do not ccnsider any applicattion t ;J , e a,,,,lona -t cocullucton Cost t tt.

tco d rficult or ca simple, too . *311aa int1b.

14V k Cr-.uCM large or too small. ' 1In'n'>".,,',' M3,,4,teel UWll' Here is a partial list of appli- -

cations where BIF flowmeters .. ... etn.lr....

are working: areworin< , ~ :.. X , .. Rectangular UVT.

• Water intake metering for n ,.

New York Clty; 96" line size uvt.rha VrT. Im" t on fmarle sav vadn'co atrstaan

sxovelcta to moter anlrstiout_ *Wi n

• Primary metering equipment We" the," r u ,e-to for the first fertilizer plant 'a moterrig ,v^

• built in the People's Republic of China

• Chilled water metering in .. 183 WeldmentType the World Trade Center's air conditioning system * '31111 r of Combination u.ctbnidol e of -

kis e-u-o wqs selectionat Corrosion os¶ n

• Eoller feed water metering nor;tot uacits-o>wUW merfnet in nuclear reactors _f "..ts trna us "Va Car"Iqtcwedofs and Dealtba

., .\ _ ectanquia asiqn.

• Compressor surge control In air reduction systems

• Air flow measurement in .. . Plastic UVT Insert Moder.182

.heating ducts Whten to- hoiVais'w tsnest acuraCy romsmni us

• Fire protection systems to OCId 4OW (.1.1.W.M,011" SIAM.d 10.*-

w.,Iat.nL provide the ability to verify a WC t 1t0 at 3W03fIqsts - r° btoln -

pump outputs during flow PwJ41r or., re an olcuest Coeltonlo rue£WL.... ,OCClU tests d oit idn.e Illne ax toundadora reaquiea.

2ol -no s v _ ;e. 1

• EIFUVTs are used by the ma;ority of pump manufac- *ide. Range Metering Systems turers to Insure the accuracy of their pump test stands i

_h u .- Zsjto~ 'I tvtlosr Valve Inlef-ie atUnhrl Bullders Iron Foundry,  !:i Wt,.r ftrw0 t wssy altetrtral cbt Providence, RI, '. ' Saat r Vos.r aetzsnt, Is Conneted to 10d gt lOcatifto about 1a85. of WAJi M 00651 rn.Uah4te t

@ 2 ~ strof evr.&I.l%_- A sqao'.S tg taGlSca:-i 11111 NeOM1F oons the va& (W Inla

.NoI mteasured b fat. UVT.

ACC iec i0 :I5 jl. 1flar "t" wd UVT.

APPLUCATION SERIESISO VTEF.18204 FAGr:

1234 D-11' CCsRP/ LEEUS A.JRrIH;UP CEZIEA.I SACN'A.

GEML SIG/LEEDS z NORTHRUP 2:'E D 3919B'_50 0005595 7 t F-ob-05

• CHARACTERISTICS OF THE UVT _

The Universal Venturi Tube is Possible Savings In Pipe (Pipe Diame the primar/ meter which pro- 30 25 20 is to a0 30 25 vides the best performance j I jtfU8rI _

characteristics found in other slcw meters. I . ! CLASStlAL~VENTURi (P P I I .. I s Heavily documented, accuracy I _ _ _

I; I FLtW TU8E i i l 15METrPi NOZZLEIJ 3,

• Lcw head lcss and ther.ecre lower operating cost f I . 1;. l ORIFIt PLATE>T 1, i 1.

• Short laying lengths: I - ASs1k 0TC-0F.OW-TEStSECTION l 1 E approximately 2.5 pipe C3m-mnsfn rt mOf r tun Ienf tts ntquttej loe t'Wafcfea do *efnmance o0 Y'tofus t',& Of Drfrmatr di diameters long

. Lcw installed cost reduced I

amount of upstream pipe *0 o,

U-:

- 2 and associated laying costs I1 C. as

.! 2 C_ .1 CL

-3 .2. a 2

, Various materials of con- CD. mu.

Vocumrntoa ACcuracy j ;,I struction available WlodPanqg I

()

Ql n )

= I of 0 l

• Meters liquids and gases - Llargy S SC!.nt 1 I__0 1 a_ 0 1 _ I 0 1 0 O the only meterwith docu- Nqilgq:tle insatolatuon - I .3_I I I I 0 I I I S mentation available; verified AdaOSIS0.to G43"Us ;IOw I IG I I I IOI I at Colorado Engineering Field Cartttatle 0 S 1 1 Q1 sJmd;s.. . I1J E.'eriment Station, Nunr, lJamenIUno to Aiging 1 I -

Coldrado :Eu1rtinCCa ManuIIc~uwr 123.. 0 I 0 C 1i 0

. No line size limit- Us anSolids 344enl rFiutdii e i* I I  ; ; 1 0 Calculation QDC. C200-1. 3 69, Rev. 0 Ii Attachment B Page B33 of B4

.'q I

t.Z' I.

INUNE BARSTOCK INSERT DESIGN IN CONTAINING PIPE Line Sizes: I" through 6" Line Sizes: 8" and larger Line Sizes: I PAGE 4 SERIES 160 WFT REF. 180.20-4 CHARACERIS TICS 1235 CG.XRAL SVI.L CYRP, LE'EMS & nKRnIsP

• NL SIG/LEEDS a NORTHRUp 21E D W i919350 0005596 9 - F-o&-o5 FLOW CONDITIONING: THE KEYTO RELIABLE FLOW METERING I

!(a3) +/-0.5% withcut calibration, and: Finally, it re-examines flcw in 20 15 10 S 0 we have docUmentation tar its throat secticn. This error-I I I lS5F UV I provP thIs.

Unlike other differential purging process provides a measurement resulting frcm the difference in the kinetic

______ LASSICA4VEN'TUR!Ij producing meters, the UVT doesn't have to accept the energy of the flow at the .. let I

• I I I w8E l inconsistencies o cpoor velcc- and the throat.

ity profiles in a flow line. The

. l ASMETYP NOZZE UVT first samples the flow in its inlet. It then liRIFICE PLA],l accelerates ancd -

13 when `nsVI'C lewnitierm of a Snort tdua jciow. l conditions f the flow.

UVrs unique, patented in-ternal hydraulic contour ccn-ditions fluid flow, prcviding accuracy and reliability not previously possible in primary n KIto$ Ihas meters. The UVT design builds I I .6 uth betil

.x trtd ayjn zd3iwtn -

in flow conditioning; flow is '.S hydraulically cushioned to  :* _: .4' E-

• prrovide a strong, stable, pre-cictable, low-noise signal BiS -s1 .,~

Hi...

UVTs guarantee accuracy`31 rho UVT-h -.. -. _

mnvosC!;Ited and dccutronte4L

'. ... .?

4 --

- .~

Calculation QDC-OZ0O 3e;, Rev. 0 At1achment B Paae 64 of 64 (0 a =1tC1 P.

I&

IMWT INLINE CAST IRON INLINE FASRICATED through e0" Une Si:ze: 2" and larger Une Sizes: 8" and larger J  %.

FLOW CONOfONINO SERIES WC UVT REFR. 150.2C-4 PAGE.3 1L236 D-13

.pi .w ,ic"%%t cnw/ Irr s it ,KmRHh;P

B IFe EngineeredFlow Applications QbC 020-I-'369 A 4ek ;; C Rev O

• icy Cl of C3 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 13 :h regarding the damages to the Alpha Steam line Venturi at Quad Cities IINuclear 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 Ventui. ..- a 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:)Ft.

i _.

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 discernable 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 01 441394331, U.S.A. (440) 519.BIFI (2431)

....... F-%v

... i44f' iQ.RIF) f7432)

BIF FbCozo0- 69 ecu Eni -neered Flow'Applications A tbkJ-1 c-ft C 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 1) will not ca,. -*

than a 0.5% 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!> - '-L.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 Dryer Incident.

My experience with Venturi at BIF, The Foxboro Company and Westfall Manufacturing cov.cs 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 F9 30685 Solon Industrial Parkway Unit F,Solon OH 44139-4331. U.S.A. (440) 519-BIFL (2431)

.'---.- ., Wr.wn'trn Fx (440) 519)-B(F2 (2432)

BI EngineeredFloviL'pplications A

-a oo2-k T- 1369 ZeU. 0 ae A 4 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 conki crie 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 wili 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, oseph M. Motta Senior Flow Engineer B I F$ 30685 Solon Industrial Parkway Unit F.Solon OH 441394331, U.S.A. (440) 519 BIFI (243 1)

I . . .P. .... cam 1111 1n7rr Il

Rosemount Nuclear Instruments Rosemount NuclearInstruments. Inc.

Eden Praime. MN 55344 USA Tel 1(6121 828-8252 Fax 1(612) 828-8280 4 April 2000 Rcf: Grand Gulf Nuclear Station message on INPO plant reports, subject Rosemount Instrument Set-point 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, lnc.(RNII) pressure transmitter models 1152, 1153 Series B.

I 153 Series D, 1154 and I 154 Series H. Aecording to our understanding, the performance variables of primary concern are those discussed in GE Instrument Setpoint Methodology document NEDC 31336, namely I. Reference Accuracy

2. Ambient Tempcrature Effect

3. Ovcrpressure Effect

4. Static Pressure Effects

5. Power Supply Effect It is RN11's undcrstanding that GE and the NRC have accepted the methodology of using transmitter testing to insure specifications arc met as a basis for confirming specifications are

+'a. The conclusions we draw regarding spccifications being t3a are based on manufacturing testing and screening, final assembly acceptance testing, periodic (e.g. every 3 months} a:'.

testing of transmitter sampics and limited statistical analysis. Please note that all performance specifications are based on zero-based ranges under reference conditions. Finally, we wish to make clear that no inferences are made with respect to confidence levels associated wV;.i any specification.

I. Reference Accuracy.

All (100%) RNII transmitters, including models I'52, 1153 Series B, 1153 Series D, 1154 and 1154 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 +3a.

2. Ambient Temperaturc 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 r model 1152 and model 1153 transmitters not tested foll6wing final assembly indicate Q.ALMULATITOJ QOV -O2oo-I-I3(9 F SEV. o T FISHER-ROSEMOUKT ATTACH MVT D ooz  %, 4N:

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conformancc to spccification. Therefore, the ambicnt temperature etfcct published in our specifications is considered +3a.

3. ()verprcssurc Effect Testing of this variable is done at thc module stage. 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 statements made for ranges 3 through 8 would also apply to ranges 9 and 10. Therefore, the overpressure effect published in our specifications is considered +;3.

4. Static Prcssurc Effects All (100%) differential prcssure sensor modules are tested for compliance with static pressure zcro ..or. Additionally. Nodels 1153 and 11'4 Ran-cs 3,6.7 Znd S art 100' tcsted after Final asscmbly for added assurance of specification compliance.' Audit testing performed on ranges 4 and 5 have shown compliance to the specification. Tlierefore. static pressure effects published in our specifications arc considered +3a.

5. l'ower Supply Effect

• Testitig ror conformance to this specification is performed on all transmitters undergoing

.saimple (audit) testing. This variable has historically exhibited extremely small performance errors and small standard deviation (essentially a mcan error of zero with a standard deviation typically lcss thlan 10% of tih specification). All transmitters tested werc found in compliance with thc spccification. 'Ilicrcflorc, powyer supply effect publishcd in our specifications is considered +3a.

Should you hiavc any further qucstions. plefisc contact Jerry Edwards at (612) 828-39 i.

Sincerely.

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

CALCULATION O -O20O-1-1369 AT TACRN1E)Tb

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(!ALCULATIO).A b\-020-- 1369 RE V- 0

-ATTAMCAGA E

-~r ElIGOP E2 Telephone Call Copies By Neil Archambo Of Bechtel To TIZ Layer Of Rcsemount

• Data June 16, 1993 Time 10:00 am subject Rosemount Model 710DU Trip/ Job No. K/A Calibration Unit Specifications File No. N/A Mr. Layer was contacted in order to clarify the specifications listed in the Rosemount Trip/Calibration System Model 710CU Operations Manual.

Clarification was required for the following:

M-aster Trip Unit (MTUI 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) tO.351/l00-F According to Mr; Layer, the above equation is to be used in the following manner:

- For ambient temperatures in the range of 600 to 90SF, Analog Output Accuracy - +/-o.15%(sPAN)

- rar ambient temperatures above 90-F, Analog Output Accuracy - +/-(0.15%(SPAN) + (0.35%)(SPAN)/lO0F) (T))

Where: AT - Ambient Temperature - 9o-F

0-ALCULATWo, abe-o-0o-j-j639 gv 0 ATTACmfisJr E Fcr example, suppose the ambient temperature at 'the trip unit locaticn is 10-F. The associated trip unit analcg cutput accuracy would be:

Analog Output Accuracy- t(b.15%(SPAN) + (0.35) (SPAN)/l00-F) (T))

Analog Output Accuracy - +/-(0.15%(4 Vdc) + (a.35i) (4 Vdc)/l100F) (30F))

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

MTU Trip output Repeatability (MTU1 .j):

MUw +/-C(.013%(SPAN) + (0.2%)(SPMANI)/lOOF) (AT))

S7J trij output Repeatability (STU,):

SlTU.Ma- +/-(0 2%(SPAN) + (0.35%) (SPFUJ)/1OO'F) (AT)

In addit'cn, Mr. Layer stated that the trip setpoint rapeatab4.!t'V equaticns listed above include reference accuracy, temperature .

drift. The equations are accurate for 6 months. Based on calibration --

procedure DIS 1400-02, the trip units are calibrated every three vzontLs.

Hovever, Mr. Layer stated that the errors would not be reduced by calibrating more frequently than 6 zonths.

The MrU and STU trip setpoints are calibrated using the calibration unit su-plied with the Model 710DU. Hr. Layer stated that errors associated w4th the calibration unit are included in the repeatability error equations lssted above. Therefore, no additional error evaluations are required for the calibration of the HTU and STU.