ML20082H388

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Rev 0 to Calculation CAL-FT-3Z-IA60A-E/IA60A1-E1, Calculation for Flow Transmitters IA60A-E & IA60A1-E1
ML20082H388
Person / Time
Site: Nine Mile Point  Constellation icon.png
Issue date: 03/15/1995
From:
NIAGARA MOHAWK POWER CORP.
To:
Shared Package
ML20082H380 List:
References
CAL-FT-3Z-IA60A, NUDOCS 9504170117
Download: ML20082H388 (36)
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Project: NINE MILE POINT NUCLEAR STATION Unit (1,2 or 0 = Both): 1 Discipline:.EierL reJ Titse Caicusation No.OpL-FT-BZ-Ti%OR-E/ZAbOAFEl 8 M DN I (Sub) system (s)

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MA Document Cross Reference (s) For additional references see page(s) l C, d 2.

Ref Ref No.

Document No, index Sheet Rev No.

Document No.

Index St.eet Rev General

References:

Remarks: 7- & tv 54, 6 'DE 2. s-M - 0160 Confirmation Requered (Yes/No):,,,,21/o.,,

Final issue Status Fate Locar:on Operations Accepted on See Page(s):

(APP /FIO/VOI): TME (Calc / Hold): /}nld issue (Yes/Nol: A/D Evaluation Number (s)/ Revision:

Component ID(s)/EPN(s)/Une Numbers: 37,_ /2 8, 74l\\

32-/4I, 32 -154, 32-/&7, 32-IM, az.j54 32 - I47, 31-/60,32-(73, 31 /&,IA&oA I44DS 7g h' Key Words: lbrutaen FN T4nswtter,

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'~ Nucleer Energy GenerelDoctne Lampany Iis CuruerAve,$enJose.CA N126 GE NE A130035141 March 1908 RECIRCULATION FLOW LOOP CALIBRATION CALCULATION FOR NIAGARA MOHAWK POWER CORPORATION NINE MILE POINT UNIT ONE Prepared by:

Ridard J.

.CE Site Engineer Nise Mlle VerlSed by:__

HE Drtecell. East 'tr Plant Upgrade Proj San Jose

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Approved by:

Hweeg Choe$foject Manager j

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SE NE A1300M141

-j March ItH IMPORTANT NOTICE REGARDING CONTENTS OF THIS REPORT Please Read Carefully a

The only undertakings of the General Electric company (GE) respecting information in this document are contained in the contract between Niagara Mohawk Power Corporation and GE, and nothing contained in this document shall be construed as changing the

- contract. The use of this information by anyone other than Niagara Mohawk Power Corporation, or for any purpose other than that for which it is intended is not authorized:

and with respect to any unauthorized use, GE makes no representation or warranty,.

expressed or implied, and assumes no liability as to the completeness, accuracy or usefulness of the information contained in this document, or that its use may not infringe on privately owned rights.

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The purpose of this calculation is to determine the correct span for the flow transmitters in the Recirculation Flow Instrumentation loops at Nine Mile Point Unit One when calibrated for rated temperature in the Recirculation Flow System.

2.0 BACKGROUND

Nine Mile Point Unit One is a nonjet pump plant which has five~ reactor recirculation loops. Each loop consists of suction piping, a suction valve, an electrically driven recirculation pump powered by an MG set, discharge piping and a discharge valve. A venturi type flow element is located in the discharge piping to measure the flow in each loop. This venturi is mounted in a vertical orientation (flow is upward) at N' e Mile m

Point Unit One. The differential pressure across the venturi taps is measured by a

-differential pressure transmitter. The output of the transmitter is processed by a square root converter and the output of the square root converter is used to indicate flow in each recirculation loop. The output of the square root converter is summed to provide total core flow indication. The vertical orientation of the venturi flow element produces a bias -

on the differential pressure seen at the transmitter due to a difference in temperature between the water in the recirculation loop and the stagnant water in the instrument tubing to the transmitter, and due to the vertical mounting of the venturi.

Instrumentation:

ID Tag.

Description FE32-122 IA61A-Venturi Flow element - SN 87189-1

- FE32-135 IA61B Venturi Flow element - SN 87189-2 FE32-148 IA61C Venturi Flow element - SN 87189-3 FE32-161 IA61D Venturi Flow element - SN 87189-4 FE32-174 IA61E Venturi Flow element - SN 87189-5 FT32-128 -

IA60A Recirculation Flow Transmitter FT32-141 IA60B Recirculation Flow Transmitter FT32,154 IA60C Recirculation Flow Transmitter FT32-167 IA60D Recirculation Flow Transmitter FT32-180 IA60E Recirculation Flow Transmitter -

FT32-134 IA60Al Recirculation Flow Transmitter FT32-147 IA60B1 Recirculation Flow Transmitter FT32-160 IA60C1 Recirculation Flow Transmitter FT32-173 IA60D1 Recirculation Flow Transmitter FT32-186 IA60El Recirculation Flow Transmitter

3.0 REFERENCES

3.1 Vendor Drawing, Universal Venturi Tube, BFI No. A-243886 3.2 Vendor Drawing, Flow Rate vs. Differential, BFI Order No. N-87189-K Page1

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3.4 Nine Mile Point Unit 2 Calculation, A10.1-A-13 Rev. O, Temperature Distribution within Instrument Lines Attached to the Reactor Coolant Pressure Boundary, see Appendix C 4.0 ACRONYMS

'd-Difference in tap elevations i

ho Uncorrected Head at Zero Flow h:

Uncorrected Head at-18 Mlbm/Hr h.

Differential Head due to Temperature Bias hm Head at High End of Span

(@ 525 F) hi Head at Low End of Span

(@ 120*F) p, Density of Recirculation System Water l

pi Density of Instrument Line Water pa Density of water at 68'F and 14.7 psia (water column, WC)

L 5.0 ASSUMPTIONS 5.1 The temperature and pressure of the Recirculation loop are assumed to be 525'F and 1000 psig. The temperature and pressure is based on design data from the venturi:

flow versus differential pressure curves The density change between the assumed pressure and the actual pressure at the venturi is small and therefore negligible. For.

example, the change in bias between 1000 psia and 1200 psia will be less than 0.7%

(< 0.04 inches WC (Water Column)).

5.2 A vertical section of the instrument line is assumed to be at the drywell ambient temperature for the same length as the distance between the venturi taps. The vertical section within the venturi between the taps is at 525'F. The drywell ambient temperature is based on temperature data taken during normal operation of the plant from temperature sensors in the area of the recirculation flow instrument lines. This data is attached in Appendix A. A walk down of the recirculation flow instrument lines in the drywell was performed to determine their configuration. This walkdown confirmed that these instrument lines are not insulated. A sketch with 'a typical layout and approximate measurements is shown in Figure 1.

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5.2.1 Horizontal runs ofinstrument piping are assumed to remain near the process -

flow temperature for several feet from the source due to natural circulation

' established in the horizontal pipe.

5.2.2 Instrument lines that run vertically down or slope down from the_ process tap, will reach ambient drywell temperatures within several inches to a foot from the point where they drop below the process tap elevation. The N* e Mile 1

m

- Point 2 calculation, Reference 3.4, supports this conclusion. The methods'

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used in this calculation can also be used to estimate the temperature distribution at Nine Mile Point 1. ' In making this estimate, it is==> mad hat t

the temperature profile is the same in the low pressure tap instrument line -

and the high pressure tap instrument line. This profile will be made up of a'

^

portion where the temperature varies and a portion at drywell ambient temperature. Figure 1 shows that the low pressure tap instrument line has a vertical run of 36 to 39 inches. If the temperature is at or near drywell ambient temperature within the first foot of the vertical run, then there will be a vertical section of pipe at drywell ambient temperature.

5.2.3 Using the methods, assumptions and heat transfer coefficients of the calculation attached in referenc^e 3.4, attached in Appendix C, an estimate of the temperature at one foot from the first 90' downward bend is calculated in

' Appendix B. The best estimate of the temperature at one foot is.

approximately 144'F. The difference in the bias assuming 120'F and 144*F.

will be less than 0.16 inches WC. Using referer.ce 3.2, this difference in the bias is equal to about 25,000 to 30,000 lbm/hr per loop at 20% core flow with 5 pumps running This is equivalent to about 0.25% rated core flow and therefore is negligible. Since the pipe continues to cool, it can be

.t 3

i assumed to be at itmbient conditions at one foot from the first 90* downward bend.

5.2.4 It can be concluded that a vertical section of piping in'the low pressure instrument line which is at drywell ambient temperature, and the vertical section of the same length inside the venturi is at 525*F. The density difference between these two vertical sections causes a bias.

5.3 The bias on the transmitter due the density differenc~e in the instrument lines is only due to the height difference in the taps on the venturi. A walk down of the plant indicated that all sensing lines (high pressure and low pressure taps) exit from the insulation and make a 90' bend downward, continuing down to about'the same elevation for both taps of each venturi, made a 90* bend and continued together horizontally to the penetration. There are no unusual instrument line runs and the only difference in density will be for the vertical sections described in 5.2 above.

5.4 The calculation is performed assuming that the reactor is at rated temperature and pressure and the drywell is at a corresponding temperature. This is the same Page 3 1

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unnins assumption that was made in the development of the calibration curves for the -

ventutis. At off rated conditions both the bias and the actual flow will be different from those at rated conditions.

6.0 PROCEDURE 6.1 The method of determining the differential pressure span is first to determine the bias due to temperature differential between the fluid density in the vertically mounted.

venturi and the corresponding portion of the low oressure tap instrument line. The -

upper end of the uncorrected transmitter span is determined by using the unique calibrated water head for each of the five venturis at the flow rate of 18 million pounds per hour. The lower end point of the uncorrected span will be 0 inches WC.

(water column), occurring at zero flow. This will result in a venturi unique s

calibration curve for the differential pressure transmitters. The effect of the bias on the uncorrected span will then be calculated by adding the bias to the upper end point and the lower end point.

7.0 CONCLUSION

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~

7.1 The differential pressure transmitter span for the recirculation flow instrumentation loop is calculated in section 8.0 and Table 1 through 5 for the condition when the temperature bias due to the mounting orientation of the venturis is considered. This will provide an input to the square root converter that will produce a square root converter output equivalent to O to 18 million pounds per hour flow for each loop

' and 0 to 90 million pounds per hour for total core flow. GENE is of the opinion that no further validation is required to support this analysis.

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= March 1996 I8.0 Calculation Calculate the Differential Head Bias Corrected to 687 and 14.7 psia Due to the Temperature Difference Between the Recirculation Fluid and the Fluid in the Instrument Lines and the Vertically Mounted Venturi

~

Recirculation Water Temperature 525 T Ref. 3.2 Instmment Line Water Temperature 120 7' Ref. Appendix A Recirculation Fluid Density at 1014.7 psi 47.6257. Ibm /cu ft Ref. 3.3 Instrument Line Density at 1014.7 psia 61.8924 lbm/cu ft Ref. 3.3 Water Density at 68T and 14.7 psia 62.3208 lbm/cu ft Ref. 3.3 Height Difference between Taps 24.711 inches Ref. 3.1 Equation:

h. = dt ( p, - pi )

-5.65694 inches WC

=

p6: -

Calculate the corrected span for the differential pressure transmitters for each venturi Equations for correcting the span:

. h = h s + h,-

hi = ho + he.

i Venturi SN 87189-1 377.76 inches WC Ref3.2 Corrected Span (0-18Mlbm/hr)

-5.7 to 372.1 inches WC '

Venturi SN 87189-2 377.5 inches WC ~

Ref3.2 Corrected Span (0-18Mlbm/hr)

-5.7 to 371.8 inches WC Venturi SN 87189-3 376.38 inches WC Ref3.2 Corrected Span (0-18Mlbm/hr)

-5.7 to 370.7 inches WC

'. Venturi SN 87189-4 376.97 inches WC Ref3.2 Corrected Span (0-18Mlbm/hr)

-5.7 to 371.3 inches WC Venturi SN 87189-5 376.43 inches WC Ref3.2 Corrected Span (0-18Mlbm/hr) -

-5.7 to 370.8 inches WC 9

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Table 1*"

Calibration Table for Venturi SN 87189 H

- Input ("H2O)

Required Output (mVDC)

-5.7 10' 2.8 10.9 88.8 20-183.2

-30 277.7 40 372.1 50:

2 Table 2*

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Calibration Table for Venturi SN 87189-2 Input ("H O)

Required Output (mVDC) 2

-5.7 10~

2.8 10.9 88.7 20 183.1 30 277.4 40-371.8 50-i Table 3' Calibration Table for Venturi SN 87189-3 Input ("H O) -

Required Output (mVDC) 2

-5.7 10-2.8 10.9 88.4 20-1 182.5 30-276.6-40 l

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370.7 50-

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  • The point at 10.9 mVDC is equivalent to 20% core flow with 5 pumps operating.

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Table 4' Calibration Table for Venturi SN 87189-4 :

- Input ("H O)

. Required Output (mVDC) 1 2

-5.7 10 2.8 -

. 10.9' 88.6-20 182.8 30 277.1 ;

371.3 50 Table 5*

Calibration Table for Venturi SN 87189-5 Input ("H O)

Required Output (mVDC) 2

-5.7 -

10 2.8 10.9 88.4 20 -

182.6 30 276.7 '

40 l

370.8 50 The point at 10.9 mVDC is equivalent to 20% core flow with 5 pumps operating.

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h m Human Factors 4 / Component Clearances A Seismic CAT II/I X Control Room Habitability i Environmental EQ A EQ Environmental Design Criteria (NMP2 only) X Seismic EQ (SQ) 1 Jet Impingement / Break Evaluation X If items are checked "YES", review is required.

  • Additional Remarks / Explanations:

PREPARED BY 1/ IA

  • M-DATE:

Y/NS CHECKED BY: AmA DATE:.26//4r 4 E 53d@$$(($3$$$$$$$$Nd$$$$hh3($hb$f$[$$d$$$}$kkhikEN$$$$$$$kk$bhbbEEbhN Format # NEP-DES-340 Rev 06 C h k" N

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7 k.D GE NE A1300351.cl March 1995 ' Appendix A e r :. QL.-FT-3L~ litwOh *E/ItttoOtti-L~j I j Rg,g ~ SE NE A130035101 ~ March 1995 DrywellTemperature Data-The drywell temperkture ofintenst in this calculation is the temperatures in area II shown on the following page. These are points 49 and 51. 120*F was chosen as the approximate -

temperature of this region. Drywell temperatures in the range of 110*F to 130'F will not -

result in a density change signi6 cant enough to change the results of the' calculation. e .e i 6 } Page A-1 ~. ' b .- l Cpt-FT-n. lth0tv-E/IMh-6( yI r l ft.R1'SskS64tDc+ryoAls ......................... o.. .i..s.2... 6.... 1 w f D AR M V1 DW 310' 0' ..[.. 4 m M W DW 290' 0* l g a l8 DW 201' 0* ..14 g" NE ,ggg ggy DW 261* C' - ~ @7 r@ 201 AREA II AREA Il gw 337 0* ,,,.,.t~ a DW 227' 0' 201 I AREAI AREA AE v111 Ilf ...........D..V... 214..'. 6..'.... L s l 282 47// 1 P ge A. _ m m-n-yen x TABLEl: DRYWELL TEMPERATURES RM DATA RTD: 201.2-53 201.2-54. 201.2-55 201.2-54 201.2 4 9 201.2-51 VOL FRAC: 0.0679 0.0679 0.0704 0.0704 0.1972 ~ 0.1972 AREA: 1(VM f(VA) 1(VM) 1(YH). Il 11 DATE TEMPERATu,RE (* F ) 01/27/83 113.80 118.30 103.30 99.30 118.60 117.60 05/20/83 99.45 101.24 72.41 72.34 99.43 98.37 06/23/83 116.92 120.30 93.04 83.14 120.47 119.96 07/15/83 114.00 118.00 . 96.00 87.00 118.00 118.00 08/13/83 113.50 119.10 97.81 90.30 114.04 117.31 l' 09/09/83 115.90 121.10 103.90 94.00 121.20 120.80 10/07/83 113.72 118.43 104.67 97.00 118.96 118.36 11/04'/83 110.60 115.10 99.70 92.30 118.10-114.30 12/02183 119.38 123.08 103.50 96.94 122.65 121.57 12/30/83 119.01 123.06 100.08 96.77 122.58 121.76 02/24/84 110.81 116.66 107.26 98.09 116.17 115.53 06/09/84 89.27 88.78 72.13 71.58 88.82 88.77 07/16/84 111.21 113.29 78.57 76.52 114.29. 114.11 08/10/84 '113.92 ' 115.88 81.68 79.75 117.40 117.10 09/07/84 112.90 114.30 '89.20 85.40 115.20 114.90 10/05/84 112.80 114.10 90.20 86.30 114.50 114.20 10/30/f4 112.90 113.50 91.10 87.00 114.40 114.10 12/02/84 108.20 100.00 99.1 ) 94.60 109.20 108.50 12/28/84 109.43 110.75 89.08 84.14 110.43 109.87 01/25/85 108.85 108.59 93.58 89.83 109.23 108.79 02/22/46 120.41 122,31 102.37 99.75 121.85. 121.'/t 03/22f88 116.70 118.06 95.62 92.89 118.32 118.09 04/19/48 117.44 118.54 96.72 93.22 118.34 118.30 05/20/85 117.90 119.10 99.10' 96.10 119.50 119.80 06/14/85 119.47 118.31 98.39 93.88 121.84 121.82 07/12/85 114.39 117.57 101.42 97.91 121.23 121.24 08/09/85 120.00 119.00 106.00 103.00 123.00 123.00 09/06/85 119.57 118.79 106.74 102.14 121.12 119.73 10/07/85 120.20 118.97 103.93 95.95 121.53 120.44-11/01/85 100.00 101.40 92.50 87.80 104.10 102.10 12/26/85 112.65 110.76 101.88 99.43 113.97 113.02 d A, 5 J TABLE 1: DRYWELL TEMPERATURES RAW DATA (COMT' D) l RTD: 201.2-83 201.2-54 201.2-56 201.2-54 201.2-49 201.2-51' VOt FRAC: 0.0679 0.0679 0.0704 0.0704 0.1972 ,0.1972 l l - AREA: l(VA) 1(VA) 1(VH) l(VH) ll 11 4 QATE TEMPEOMRE (*F) 01/25/84 84.19 M.20 75.31 74.83 86.79 85.00 l 01/28/M M.19 M.20 75.31 74.83 L 86.79 85.00 ' - i 02/21/88 107.20 103.50 .96.30 90.M 107.48 106.64 06/16/06 99.M 99.19 48.57 49.21 99.00 97.79 j. 06/15/88 99.10 99.50 M.40 67.90 - 97.80 97.40 - 07/13/M 92.41 91.M 78.48 78.73 91.70 92.13 08/22/06 106.98 110.21-78.36 78.36 116.44 115.48. j 10/03/84 117.87 129.00 80.M 80.58 123.48 123.36 11/01/98 114.70 126.81 80.30 80.31-120.75 120.14_ 11/26/06 108.9 122.00 78.40 78.40 115.70 114.90 12/28/M 106.47 118.17 76.82 ' 77.00 111.99 111.m 01/23/87 104.00 118.00 78.00 76.00 111.00 110.00 02/20/87 107.80 120.70 70.70 70.90 115.00 113.50 03/19/87. 107.00 121.00 72.00 72.00 115.00 114.00 l. 04/14/87 108.80 123.20. 73.10 73.20 118.10 116.80 07/10/87 113.10 130.40 78.10 78.20 122.00 122.5 08/07/87 107.90 123.00 40.20 80.30 116.80 116.80 09/06/87 112.00 129.40 80.80 80.40 120.90 120.90 1042/87 110.00 128.30 41.10 81.20 119.80 '119.40 - 10/3047 100.00 132.00-78.00 79.00 121.00 120.00 l: 11/2847 100.00 1M.00 78.00 79.00 122.00 120.00 12/0647 98.80 95.10 ~ 92.00 73.00 96.70 H.40 ' 12/24/87 92.00 92.50 72.40 74.20 93.40

92. 2 4

1 l i I it g e A+ II CN - FT-32. - Ze@-r=/EnucN-GE-NE A130035101 March 1M5 Appendix B i 02 -fT*-32 ~IAWA-E/AMI-E) 7ea. b GE NE-A130035101 March 1M5 Calculation to estimate the temocrature at one foot Recirculation Fluid Temperature, T, 525 'F Assumption 5.1 Drywell Ambient Temperature, T. 120 'F Appendix A 2 Convection Heat Transfer Coefficient, h 1 BTU /(hr ft *F) Ref. 3.4 Pipe Outside Diameter,1 inch pipe, c. 1.315 inches Conductive Heat Transfer Coefficient, 316 SS, k 9.3 BTU /(hr ft *F) Ref 3.4" Conductive Heat Transfer Coefficient, H20, k 0.36 BTU /(hr ft 'F) Ref 3.4" Pipe Wall Thickness (Schd 80) 0.179 inches Pipe Metal Area 0.63882 Pipe Inside Area 0.71931 " These number will be conservative and changing them will have a negligible impact on this estimate. '" Pipe size and schedule are found in the Piping Specification for System 32, PSRS 32, the NMPI plant data base and drawing A-69020-C. Temperature at a length of 12 inches Using Equation: T = ( T, - T. ) e* + T. where m = ( 4 h / k / do )" - Ref. 3.4 Using: k for SS k for H O Combined

  • 2 175.854 120.017 143.955
  • Combines the k based on the ratios of the areas of stainless steel and water. This is the best estimate of the actual temperature at one foot.

Temperature Density at 1014.7 psia 525 p525 47.6257 lbm/cu ft Ref. 3.3 144 piu. 61.5006 lbm/cu ft Ref. 3.3 120 pi2o. 61.8924 lbm/cu ft Ref. 3.3

d..

24.711 Ref 3.1 p6. 62.3208 lbm/cu ft at 14.7 psia Ref. 3.3 Error due to temperature not at ambient (pressure = 1014.7 psia) Ah = d (( p 2c - p525 ) - ( pie - p523 )) / P6: 0.15537 i Page B-1 QMk-FT 5L-N-E.@pt -gg k.s GE NE A130035101 March 1995 Appendix C so 9 + ^ ^ -- m . OL-Fr-n-TacHyraca-ef Tev.O ATTACIDENT 1 STONE & WEBSTER ENGINEERING CORPORATION CHERRY HILL. OPERATIONS CENTER INTER 0lTICE MEMORANDUM @ $$ 32177 9 A *es.es SUBJECT TINAL QA CATEGoiY I DATE CALCULATION REVIEW RECORD FRou TO Document Control - cc Tanadden Calculation Job took No. M /O' /~M I have performed the final review of the calculation listed below and have determined that it can be considered final with no update of input infor-nation. Please file this ION with the original calculation in the appro-priate job book. Calculation No.: A /8' IM ** /E NU O ~)irMM-A1'dnai M51St/~T/W W/7Wf / [MW Calculation

Title:

Nd.sps.hY Soya At Date of Calculation:

~ //* 3 "' 8 /

Validity Review (check if statement is accurate):

9 1

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1.

All information requiring confirmation has been confirmed.

If necessary, the requirements of EAP,5.3 Section 10 have i

been satisfied.

2.

All input data to the calculation is valid. Even though some of the data was.obtained free outdated references, the data has not changed enough to affect the conclusions of the calculation, and a calculation revision to update these references is not warranted.

3.

I see no other reason to revise the' calculation.

Reviewer's Signature /Date

/ V-2@d e

/

HIER APR 291986 m.L Aum Supervisor's Signature /Date

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l' NIAEARA MOHAWK NUCLEAR ENGINEERING CALCULATION NUMBER REQUEST FROM M 6sepenG5hi DATE J/z/93-

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TO DOCUMENT CONTROL SUBJECT Nine Mile Point Nuclear Station, Unit _L PROJECT:

NAJOR ORDER No. 4'/ 4 _ _ _ _ _

istPI IEEX N0. _E_2_/ _ _ _ _ _

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i For New Calculations and Contractor / Vendor Originated requests ONLY.

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