Text

Allowable Swhe Tube Blockage Vs Vhs Temp
	ML20078A397
Person / Time
Site:	Crystal River
Issue date:	12/06/1994
From:	; FLORIDA POWER & LIGHT CO.
To:	;
Shared Package
ML20078A388	List: 3F0195-01, Provides Addl Info as Requested in Insp Rept 50-302/94-26. Util Believes That Swsopa Conducted by Personnel Was Thorough & Comprehensive.Design Analysis/Calculation M94-0056,rev 0 Encl; ML20078A397;
References
	M94-0056, M94-56, NUDOCS 9501240389
	Download: ML20078A397 (79)
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e.x M Finridg INTEROFFICE CORRESPONDENCE 1

Power conPoRAnow Nuclear Engineering 4,22 86 [

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SUBJECT:

Crystal River Unit No. 3 Quality Document Transmittal-Analysis / Calculations File: CALC To: Records Management-NR2A The following analysis / calculation package is submitted as the OA Record copy:

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and list 99 separate sMt.,

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MAR / Project File Eval. and Analysis / Calc. Summary Mgr.. Nuct. Config. Mgt.

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Florida P'owp'*r ANALYSIS / CALCULATION SUNNARY oncruwe courax wo.

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DOCUMENT IDENTIFICATION NUMBER M

94-00 G 0

ims aasorcAnow paxone Allowable Tube Blockage vs. UHS Temperature E Sesety neinned j

Non Safety Related waterwuumsvenz EQUIP 5-38 venoun ana==#r wuumen N/A REVISIM ITEMS REVISED APPRQVALS Design Engineer initialissue I

Date

[N[9 /

Verification Engineer (('M Dete/ Method *

///2.'9/96 7

j Supervisor (d

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VERIFICATION METHODS: R - Design Review; A - Alternate Calculation; T - Qualification Testing r

l oescase estow w mernoo oc venacArea wAs ornen inA= ossian neview i

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Ptneoes suumm The ournose d this calculation is to identify when a second SWHE heat exchancer should be cleaned based uoon the l

amount d blockaoe that is noted durino the cleanino d the first SWHE. This decision is a function of the Gulf of Mexico (UHS) temoerature reautre suumm A orsoh d cercent d blockaos detected vs. UHS temoerature is identified in Attachment #6.

i r

I Rev. 4/02 RET: LNe of Piant RESP: Nuclear engineering soo e25

e pga DESIGN ANALYSIS / CALCULATION Crystal River Unit 3 coar m ron Sheet 1

of 4 occwun nonvarxnee.

msvuon anuwse atuamtas M94-0056 0

equip 5-38 I

JECTION 1 - PURPOSE The purpose of this analysis is to calculate the percent of macrofouling (tube pluggage and blockage) that is acceptable for the SWHE's.

If the blockage noted by visual inspection during the weekly cleaning of the first heat SWHE is greater than

)

that allowed per Attachment #6, for the identified UHS temperature, a second SWHE should be cleaned.

l SECTION 2 - DESIGN INPUTS 1.

The amount of heat required to be removed from the SW system is 140.38 E6 btu /hr. (Ref. 2) 2.

Three (3) heat exchangers are required to be in service. (Ref. 3) l

,SECTION 3 - ASSUMPTIONS i

1.

RW flow rate decreases with an increase in the amount of tube blockage.

2.

The RW flow rates for various percentages of inlet side tube blockage are taken from Ref. 1 (preliminary), and are as follows:

Percent Blocked Total RW Flow Rate (gpm)

Flow per HX (gpm) i

.0%

13,900 4633 20%

13,600 4533 30%

13,150 4383 40%

12,550 4183 50%

11,700 3900 If the subject calculation is issued with the RW flow rate resulting from blockage being less than that ide'ntified above, a revision to this calculation is necessary. This assumes equal flow to each heat exchanger.

3.

No "second pass" tubes in any heat exchanger are clogged.

4.

Three (3) of the four (4) SWHE's are in service.

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ga DESIGN ANALYSIS / CALCULATION Crystal River Unit 3 comwA m m Sheet _2_ or 4 Doctt4DrT mENTFICAT90ffto.

REVEION Rh194AR/SP NUMBER /FRJi i

M94-0056 0

equip 5-38 i

SECTION 4 - REFERENCES 1.

M94-0050, SWHE Heat Removal Capacity with Partially Clogged Tubes.

(preliminary).

1 2.

M94-0052, Post LOCA NSCCC Heat Loads, Rev. O.

3.

CR3 Technical Specification, Section 3.7.7.

SECTION 5 - DETAILED ANALYSES /CALCULATJ.QNg The amount of available heat exchanger area can be calculated using the following formula:

2 Available Area (ft ) = 8600 - ((blockage (%))/2}*(8600) l 1

Percent Blocked Available Area 1

10%

8170 l

4 l

20s 7740 30%

7310 l

40%

6880 50%

6450 The maximum UHS temperature which can occur for the defined available area is determined using SWHE.KRC.

Validated 11/14/94.

The spreadsheets are attached, as Attachment 1 for 10% blockage through Attachment

5 for 50% blockage.

l

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SECTION 6 - RESULTS/CONCLUSIONE I

The maximum allowable UHS temperatures and allowable percent of clogging are j

l identified in Attachment's 1 through 5.

i i

The graph of allowable UHS temperature vs. allowable blockage is Attachment #6.

l It should be noted that in order to make the analysis more conservative, a second j

plot of UHS temperature vs. percent blockage is included. This plot should be used l

when deciding whether a second heat exchanger should be cleaned. -The 5*F margin was chosen on the basis of engineering judgement to provide additional margin when considering the unknowns associated with SW/RW heat removal capability (e.g. tube and m

um sn

Florida DESIGN ANALYSIS / CALCULATION Power Crystal River Unit 3 coarounow Sheet 3 of 4 oocwm ammunomo.

uvmon asuwse m uuna M94-0056 0

equip 5-38 shell side fouling, the condition of the other heat exchangers, and the possible temperature changes in the UHS that could occur prior to the next heat exchanger surveillance.)

The graph is used as follows:

1.

If the first SWHE was 40% blocked and the Gulf Temperature * (UHS) was 93*F (pt.

1), then a second heat exchanger should be cleaned. If the first SWHE was 40%

blocked, but the gulf was only 90*F (pt. 2), a second SWHE does not need to be cleaned.

2.

If the first SWHE was 50% blocked or greater, the Gulf Temperature (UHS) is insignificant, and the second SWHE should be cleaned because of the likely blockage that has already occurred in the remaining SWHE's.

SECTION 7 - ATTACEMENTS Attachment #1, SWHE performance with 10% Blocked (5 sheets)

Attachment #2, SWHE performance with 20% Blocked (5 sheets)

Attachment #3, SWHE performance with 30% Blocked (5 sheets)

Attachment #4, SWHE performance with 40% Blocked (5 sheets)

Attachment #5, SWHE performance with 50% Blocked (5 sheets)

Attachment #6, UHS Temperature vs. Allowable Blockage (1 sheet) i O

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DESIGN ANALYSIS / CALCULATION

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OPERATING CONDITIONS HEAT EXCHANGER PHYSICAL PARAMETERS SW System Inlet Temperature (TI)(Deg. F 142.58 Number of Tubes (n) 1090 SW System Outlet Temperature (T2)(Deg.F 110.00 Tube OD (Do)(inches) 0.75 RW System Inlet Temperacure (T3)(Deg.F) 100.10 Tube ID (D1)(inches)'

O.62 RW System Outlet Temperature (T4)(Deg.F 120.32 Tube Wall Thickness (tw)(inches) 0.065 Tube Thermal Conductivity (kw)(Btu /Hr-Ft-Deg 30.00 1

SW Heat Exchanger Heat Load (Q)(Btu /Hr) 4.68E+07 Tube Fluid Density (pt)(lbm/Ft*3) 64.00 Tube Fluid Heat capacity (Cpt)(Btu /lbat-DegF) 0.94 SW Flowrate (GPM) 2800 Shell Fluid Density (ps)(lbs/Ft*3) 62.10' i

kW Flowrate (GPM) 4633 Shell Fluid Heat Capacity (Cps)(Btu /lbst-DegF 1.00 i

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FLORIDA PONER CORPORATION-CRYSTAL RIVER UNIT 3 OPERATING CONDITIONS HEAT EXCHANGER PHYSICAL PARAMETERS SW System Inlet Temperature (TI)(Deg. F 142.58 Number of Tubes (n) 1090 SW System Outlet Temperature (T2)(Deg.F 110.00 Tube OD (Do)(inches) 0.75 RW System Inlet Temperature (T3)(Deg.F) 99.00 Tube ID (D1)(inches) 0.62 '

RW System Outlet Temperature (T4)(Deg.F 119.77 Tube Wall Thickness (tw)(inches) 0.065 Tube Thermal Conductivity (kw)(Btu /Hr-Ft-Deg 30.00 SW Heat Exchanger Heat Load (Q)(Btu /Hr) 4.68E+07 Tube Fluid Density (pt.)(1ba/Ft*3) 64.00 Tube Fluid Heat Capacity (Cpt)(Btu /lbe-DogF) 0.94 SW Flowrate (GPM) 2800 Shell Fluid Density (ps)(lbs/Ft*3) 62.10 i

RW Flowrate (GPM) 4533 Shell Fluid Heat capacity (Cps)(Stu/lbe-DegF 1.00 Cleanliness Factor (CF) 0.80 Effective Heat Transfer Area (A)(Ft*2) 7740.00 f

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16.19 0.48 1.57 0.87 14.09 109.39 126.29 117.84 122.07 2.91 8.60E+02 16.23 0.48 1.57 0.87 14.12 109.39 126.34 117.86 122.10 2.91 8.60E+02 16.27 0.47 1.58 0.87 14.16 109.39 126.39-117.89 122.14 2.91 8.60E+02 16.31 0.47 1.58 0.87 14.19 109.39 126.44 117.91 122.18 2.91 8.60E+02

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16.35 0.47 1.59 0.87 14.23 109.39 126.49 117.94 122.22 2.91 8.61E+02 16.39 0.47 1.59 0.87 14.26 109.39 126.54 117.96 122.25 2.91' 8.61E+02 16.43 0.47 1.60 0.87 14.30 109.39 126.59 117.99 122.29 2.91 8.61E+02 16.47 0.47 1.60 0.87 14.33 109.39 126.64 118.01 122.33 2.91 8.61E+02 16.51 0.47 1.61 0.87 14.36 109.39 126.69 118.04 122.37 2.91 8.61E+02 16.55 0.47 1.61 0.87 14.40 109.39 126.74 118.06 122.40 2.91 8.61E+02 i

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1.98E-04 113.61 8.84 2.38E+03 535.05 428.04 4.67E+07 1.98E-04 113.62 8.84 2.38E+03 535.10 428.08 4.68E+07 1.98E 113.64 8.84 2.38E+03 535.16 428.13 4.69E+07 1.98E-04 113.65 8.84 2.38E+03 535.21 428.17 4.70E+07 1.98E-04 113.66 8.84 2.38E+03 535.27 428.21 4.72E+07 1.98E-04 113.67 8.84 2.38E+03 535.32 428.26 4.73E+07 1.98E-04 113.69 8.84 2.38E+03 535.38 428.30 4.74E+07 1.98E-04 113.70 8.84 2.38F+03 535.43 428.35 4.75E+07 1.98E-04 113.71 8.84 2.38E+03 535.49 428.39.

4.76E+07 1.98E-04 113.72 8.84 2.38E+03 535.54 428.43 4.77E+07 1.98E-04 113.74 8.84 2.38E+03.

535.60 428.48 4.79E+07 I

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HEAT EXCHANGER THERNAL BALANCING MODEL [SWHE-1A/1B]

FLORIDA POWER CORPORATION-CRYSTAL RIVER UNIT 3 r

OPERATING CONDITIONS IIEAT EXCHANGER PHYSICAL PARAMETERS SW System Inlet Temperature (TI)(Deg. F 142.58 Number of Tubes (n) 1090 SW System Outlet Temperature (T2)(Deg.F 110.00 Tube OD (Do)(inches) 0.75 0.62

l RW System Inlet Temperature (T3)(Deg.F) 97.60 Tube ID (D1)(inches).

0.065 RW System Outlet Temperature (T4)(Deg.F 119.08 Tube Wall Thickness (tw)(inches)

Tube Thermal Conductivity (kw)(Btu /Hr-Ft-Deg 30.00 SW Heat Exchanger Heat Load (Q)(Btu /Hr) 4.68E+07 Tube Fluid Density (pt)(lbm/Ft"3) 64.00 Tube Fluid Heat capacity (Cpt)(Btu /lbe-DegF) 0.94 SW Flowrate (GPM) 2800 Shell Fluid Density (ps)(lbe/Ft*3) 62.10 RW Flowrate (GPM) 4383 Shell Fluid Heat Capacity (Cpe)(Btu /lbe-DegF 1.00 Cleanliness Factor (CF) 0.80 Effective Heat Transfer Area (A)(Ft"2) 7310.00 I

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% Diff Q(Btu /Hr) 4.68E+07

-0.0827 4.68E+07 4.70E+07

-0.3284 4.68E+07 4.71E+07

-0.5739 4.68E+07 4.72E+07

-0.8190 4.68E+07 4.73E+07

-1.0640 4.68E+07 4.74E+07

-1.3087 4.68E+07 4.75E+07

-1.5531 4.68E+07 4.76E+07

-1.7973 4.68E+07 4.78E+07

-2.0413 4.68E+07 4.79E+07

-2.2850 4.68E+07 4.80E+07

-2.5285 4.68E+07 m o z fO y 6

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Ms(1bm/Hr)

Mt(1be/Hr) delTs delTt T1 T2 T3 T4 GTD LTD 1.44E+06 2.32E+06 32.58 21.48 142.58 110.00 97.60 119.08 23.50 12.40 1.44E+06 2.32E+06 32.58 21.48 142.68 110.00 97.60 119.08 23.60 12.40 4

1.44E+06 2.32E+06 32.58 21.48 142.78 110.00 97.60 119.08 23.70 12.40 1.44E+06' 2.32E+06 32.58 21.48 142.88 110.00 97.60 119.08 23.80 12.40 1.44E+06 2.32E+06 32.58 21.48 142.98 110.00 97.60 119.08 23.90 12.40 1.44E+06 2.32E+06 32.58 21.48 143.08 110.00 97.60 119.08 24.00 12.40 1.44E+06 2.32E+06

'32.58 21.48 143.18 110.00 97.60 119.08 24.10 12.40 1.44E+06 2.32E+06 32.58 21.48 143.28 110.00 97.60 119.08 24.20 12.40 1.44E+06 2.32E+06 32.58 21.48 143.38 110.00 97.60 119.08 24.30 12.40 1.44E+06 2.32E+06 32.58 21.48 143.48 110.00 97.60 119.08 24.40 12.40 1.44E+06 2.32E+06 32.58 21.48 143.58 110.00 97.60 119.08 24.50 12.40 i

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R F

LMTD' Ttavg Tsavg Twavg tfo' Veo.

ho 17.36 0.48 1.52 0.87 15.11 108.34 126.29 117.32 121.80 2.91 8.59E+02 17.40 0.48 1.52 0.87 15.14 108.34 126.34 117.34 121.84 2.91 8.59E+02 17.45 0.48 1.53 0.87 15.18 108.34 126.39 117.37 121.88 2.91 8.59E+02 17.49 0.47

'1.53 0.87 15.21 108.34 126.44 117.39 121.92 2.91 8.60E+02 17.53 0.47 1.54 0.87 15.25 108.34 126.49 117.42' 121.95 2.91 8.60E+02 17.57 0.47 1.54 0.87 15.28 108.34 126.54 117.44 121.99 2.91 8.60E+02 17.61 0.47 1.54 O.87 15.32 108.34 126.59 117.47 122.03 2.91 8.60E+02 17.65 0.47 1.55 0.87 15.35 108.34 126.64 117.49' 122.07 2.91 8.60E+02 l

17.69 0.47 1.55 0.87 15.39 108.34 126.69 117.52 122.10 2.91 8.60E+02

[

17.73 0.47 1.56 0.87 15.42 108.34 126.74 117.54 122.14 2.91 8.60E+02 17.77 0.47 1.56 0.87 15.46 108.34 126.79 117.57 122.18 2.91 8.60E+02 i

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1.98E-04 112,83 8.55 2.31E+03 530.20 424.16 4.68E+07 1.98E-04 112.84 8.55 2.31E+03 530.25 424.20 4.70E+07 1.98E-04 112.85 8.55 2.31E+03 530.31 424.25 4.71E+07 1.98E-04' 112.87 8.55 2.31E+03 530.36 424.29 4.72E+07 1.98E-04 112.88 8.55 2.31E+03 530.42 424.33 4.73E+07 1.98E-04 112.89 8.55 2.31E+03 530.47 424.38 4.74E+07 1.98E-04 112.90 8.55 2.31E+03 530.53 424.42 4.75E+07 1.98E-04 112.92 8.55 2.31E+03 530.58 424.47 4.76E+07 1.98E-04 112.93 8.55 2.31E+03 530.64 424.51 4.78E+07.

1.98E-04 112.94 8.55 2.31E+03 530.69 424.55 4.79E+07 1.98E-04 112.95 8.55 2.31E+03 530.75 424.60 4.80E+07 D O >

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HEAT EXCHANGER THERMAL BALANCING MODEL [ SWIM-1A/15]

FLORIDA POWER CORPORATION-CRYSTAL RIVER UNIT 3 OPERATING CONDITIONS HEAT EXCHANGER PHYSICAL PARAMETERS SW System Inlet Temperature (TI)(Deg. F 142.58' Number of Tubes (n) 1090 SW System Outlet Temperature (T2)(Deg.F 110.00 Tube OD (Do)(inches) 0.75 RW System Inlet Temperature (T3)(Deg.F) 96.00 Tube ID-(DL)(inches) 0.62 RW System Outlet Temperature (T4)(Deg.F 118.50 Tube % ' Thickness (tw)(inches) 0.065 Tube "-r smal Conductivity (kw) (Btu /Hr-Ft-Deg 30.00 SW Heat Exchanger Heat Load (Q)(Btu /Hr) 4.68E+07 Tube lauld Density (pt)(1bm/Ft"3) 64.00 Tube Fluid Heat Capacity (Cpt)(Btu /lbe-DegF) 0.94 SW Flowrate (GPM) 2800 Shell Fluid Density (ps)(lbs/Ft 3) 62.10 RW Flowrate (GPM) 4183 Shell Fluid Heat Capacity (Cps)(Stu/lbe-DegF 1.00 Cleanliness Factor (CF)

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0.80 Effective Heat Transfer Area (A)(Ft"2) 6880.00 m o >

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% Diff Q(Btu /Hr) 4.66E+07 0.4170 4.68E+07 4.67E+07 0.1814 4.68E+07 4.68E+07

-0.0539 4.68E+07 I

4.69E+07

-0.2890 4.68E+07 4.70E+07

-0.5238 4.68E+07 4.72E+07

-0.7584 4.68E+07 4.73E+07

-0.9928 4.68E+07 4.74E+07

-1.2270 4.68E+07 4.75E+07

-1.4609 4.68E+07 4.76E+07

-1.6946 4.68E+07 4.77E+07

-1.9281 4.68E+07 vs a 2

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Mt(1 bat /Hr) delTs delTt T1 T2 T3 T4 GTD LTD 1.44E+06 2.21E+06 32.58 22.51 142.58 1'10.00 -

96.00 11e.51 24.07 14.00 1.44E+06 2.21E+06 32.58 22.51 142.68 110.00 96.00 118.51 24.17 14.00 1.44E+06 2.21E+06 32.58 22.51 142.78 110.00 96.00 118.51 24.27 14.00 1.44E+06-2.21E+06 32.58 22.51 142.88 110.00 96.00 118.51 24.37 14.00 1.44E+06 2.21E+06 32.58 22.51 142.98 110.00 96.00 118.51 24.47 14.00

+

1.44E+06 2.21E+06 32.58 22.51 143.08 110.00 96.00 118.51 24.57 14.00 1.44E+06 2.21E+06 32.58 22.51 143.18 110.00 96.00 118.51 24.67 14.00 1.44E+06 2.21E+06 32.58 22.51 143.28 110.00 96.00 118.51 24.77 14.00 1.44E+06 2.21E+06 32.58 22.51 143.38 110.00 96.00 118.51 24.87 14.00 1.44E+06 2.21E+06 32.58 22.51 143.48 110.00 96.00 118.51 24.97 14.00 1.44E+06 2.21E+06 32.58 22.51 143.58 110.00 96.00 118.51 25.07 14.00 9

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LMTD' Ttavg Tsavg Twavg tfo vmo ho 18.58' O.48 1.45 0.87 16.17 107.25 126.29 116.77 121.53 2.91 8.58E+02 18.63 0.48 1.45 0.87 16.21 107.25 126.34 116.80 121.57 2.91 8.58E+02 18.67 0.48 1.46 0.87 16.24 107.25 126.39 116.82 121.61 2.91 8.59E+02 18.71 0.48 1.46 0.87 16.28 107.25 126.44 116.85 121.64 2.91 8.59E+02 18.75 0.48 1.47 0.87 16.31 107.25 126.49, 116.87 121.68 2.91 8.59E+02 18.79 0.48 1.47 0.87 16.35 107.25 126.54' 116.90 121.72 2.91 8.59E+02 18.84 0.48 1.47 0.87 16.39 107.25 126.59 116.92 121.76 2.91 8.59E+02 18.88 0.48 1.48 0.87 16.42 107.25 126.64 116.95 121.79 2.91 8.59E+02 18.92 0.48 1.48 0.87 16.46 107.25 126.69 116.97 121.83 2.91 8.59E+02 18.96 0.47 1.49 0.87 16.50 107.25 126.74 117.00 121.87 2.91 8.59E+02 19.00 0.47 1.49 0.87 16.53 107.25 126.79 117.02 121.91 2.91 8.60E+02

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1.98E-04 112.01 8.16 2.21E+03 523.70 418.96 4.66E+07 1.98E-04 112.03 8.16 2.21E+03 523.75~

419.00 4.67E+07 1.98E-04 112.04 8.16 2.21E+03 523.81 419.05 4.68E+07 1.98E-04 112.,05 8.16 2.21E+03 523.86 419.09

' 4.69E+07 j

1.98E-04 112.08 8.16 2.21E+03 523.97 419.18

.4.70E+07 1.98E-04.

112.06 8.16 2.21E+03 523.92 419.13 4.72E+07

'l 1.98E-04 112.09 8.16 2.21E+03 524.02 419.22 4.73E+07 1.98E-04 112.10 8.16 2.21E+03 524.08 419.26 4.74E+07 1.98E-04 112.11 8.16 2.21E+03 524.13 419.30-4.75E+07-1.98E-04 112.13 8.15 2.21E+03 524.18 419.35

. 4.76E+07 1.98E-04 112.14 8.16 2.21E+03 524.24 419.39 4.77E+07 l

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HEAT EXCHANGER THERNAL BALANCING'MODEL (SWHE-1A/1B]

l FLORIDA POWER CORPORATION-CRYSTAL RIVER UNIT 3 I

OPERATING CONDITIONS' HEAT EXCHANGER PHYSICAL PARAMETERS l

SW System Inlet Temperature (T1)(Deg. F 142.58 Number of Tubes (n)

.1090 SW System Outlet Temperature (T2)(Deg F 110.00 Tube OD (Do)(inches) 0.75 RW System Inlet Temperature (T3)(Deg.F) 93.70 Tube ID (D1)(inches) 0.62

-RW System Outlet Temperature (T4)(Deg.F 117.84 Tube Wall Thickness (tw)(inches) 0.065 Tube Thermal Conductivity (kw)(Btu /Hr-Ft-Deg 30.00 SW Heat Exchanger Heat Load (Q)(Btu /Hr) 4.68E+07 Tubc Fluid Density (pt)(lbm/Ft*3) 64.00 Tube Fluid Heat capacity (Cpt)(Btu /lbe-DogF) 0.94 SW Flowrate (GPM) 2800 Shell Fluid Density (ps)(lbs/Ft*3) 62.10 RW Flowrate (GPM) 3900 Shell Fluid Heat Capacity (Cps)(Btu /lbe-DegF 1.00 Cleanliness Factor (CF) 0.80 Effective Heat Transfer Area (A)(Ft 2) 6450.00 e

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Q cale t Diff Q(Btu /Hr) 4.67E+07 0.2878 4.68E+07 4.68E+07 0.0622 4.68E+07 4.69E+07

-0.1632 4.68E+07 4.70E+07

-0.3883 4.68E+07 4.71E+07

-0.6133 4.68E+07 4.72E+07

-0.8380 4.68E+07 4.73E+07

-1.0625 4.68E+07 4.74E+07

-1.2867 4.68E+07 4.75E+07

-1.5108 4.68E+07 4.76E+07

-1.7346 4.68E+07 4.77E+07

-1.9583 4.68E+07 3 0 >

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Ma(lbm/Hr)

Mt (lbet/Hr) delTs delTt T1 T2 T3 T4 GTD LTD 1.44E+06 2.06E+06 32.58

24. 4 142.58 110.00 93.70 117.84 24.74 16.30 1.44E+06 2.06E+06 32.58 24.14 142.68 110.00 93.70 117.84 24.84 16.30 1.44E+06 2.06E+06 32.58 24.14 142.78 110.00 93.70 117.84 24.94 16.30 1.44E+06' 2.06E+06 32.58 24.14 142.88 110.00 93.70 117.84 25.04 16.30 1.44E+06 2.06E+06 32.58 24.14 142.98 110.00 93.70 117.84 25.14 16.30

+

1.44E+06 2.06E+06 32.58 24.14 143.08 110.00 93.70 117.84 25.24 16.30 1.44E+06 2.06E+06 32.58 24.14 143.18 110.00 93.70 117.84 25.34 16.30 1.44E+06 2.06E+06 J2.58 24.14 143.28 110.00 93.70 117.84 25.44 16.30 1.44E+06 2.06E+06 32.58 24.14 143.38 110.00 93.70 117.84 25.54 16.30 1.44E+06 2.06E+06 32.58 24.14 143.48 110.00 93.70 117.84 25.64 16.30 1.44E+06 2.06E+06 32.58 24.14 143.58 110.00 93.70 117.84 25.74 16.30

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on

LMTD P

R F

LMTD' Ttavg Tsavg Twavg tfo Vtno ho 20.23 0.49 1.35 0.87 17.60 105.77 126.29 116.03 121.16 2.91 8.57E+02 20.27 0.49 1.35 0.87 17.64 105.77 126.34 116.06 121.20 2.91 8.57E+02 20.32 0.49 1.36 0.87 17.67 105.77 126.39 116.08 121.24 2.91 8.57E+02 20.36 0.49 1.36 0.87 17.71 105.77 126.44 116.11 121.27 2.91 8.58E+02 20.40 0.49 1.37 0.87 17.75 105.77 126.49 116.13 121.31 2.91 8.58E+02

+

20.45 0.49 1.37 0.87 17.79 105.77 126.54 116.16 121.35 2.91-8.58E+02 20.49 0.49 1.37 0.87 17.83 105.77 126.59 116.18 121.39-2.91 8.58E+02 20.53 0.49 1.38 0.87 17.86 105.77 126.64 116.21 121.42 2.91 8.58E+02 20.58 0.49 1.38 0.87 17.90 105.77 126.69 116.23 121.46 2.91 8.58E+02 20.62 0.48 1.39 0.87 17.94 105.77 126.74 116.26 121.50 2.91 8.58E+02 20.66 0.48 1.39 0.87 17.98 105.77 126.79 116.28 121.54 2.91 8.58E+02 QO Z O >

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1.98E-04 110.90 7.60 2.08E+03 513.90 411.12 4.67E+07 1.98E-04 110.91 7.60 2.08E+03 513.95 411.16 4.68E+07 1.98E-04 110.93 7.60 2.08E+03 514.00 411.20 4.69E+07 1.98E 110.94 7.60 2.08E+03 514.05 411.24 4.70E+07 1.98E-04 110.95 7.60 2.08E+03 514.11 411.28 4.71E+07 1.98E-04 110.96 7.60 2.08E+03 514.16 411.33' 4.72E+07 1.98E-04 110.98 7.60 2.08E+03 514.21 411.37 4.73E+07 1.98E-04 110.99 7.60 2.08E+03 514.26 411.41 4.74E+07 1.98E-04 111.00 7.60 2.08E+03 514.32 411.45 4.75E+07 1.98E-04 111.01 7.60 2.08E+03 514.37 411.50 4.76E+07 1.98E-04 111.03 7.60 2.08E+03 514.42 411.54 4.77E+07 t

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ATT4elMENT' 4 6 h

DESIGN ANALYSIS / CALCULATION Crystal River Unit 3 Sheiet I

of-l l

XXlUMENT IDENTIFICATION NUMSER REYtSION RE144ARISP NUMBEFVFILE l

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pqc #,g39 ISSUE DATE EVALUATIM OPERASILITY 9'

~ -'

Als N00-14 12/03/93

~

DETERMINIM SAFETY 1

PAGE l

FUNCTION STATUS

'_l REV. 5

15 0F 21 lNUCLEAROPERATIONS l

ATTACHMENT A-3 1

(Page 1 of 3)

OPERABILITY EVALUATION FORM i

1.

Initiating Individual:

A74ES##ll Date: /2-4 -W Nb 2.

Initiating Document:

j 3.

Affected Item (System, Subsystem or Componen )

6W-lttekar derMM

$$1r l 6(n/C Asl$nd 6Hkm l

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4.

System Designation (s)

SU 5.

Tag Number (s)

StoNt=-/4-

.SYuMG-If 5(U//S-/c swe-a>

6.

Specified Safety Function (s) of Affected Item Ssofls denbhd til:.kr Av nmsthf6l Ire km Guh supoW 6A. At4ws drs:sn y

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1 10 1

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4 4

1' ISSUE DATE EVALUATIM OPERABILITY i

AM N00-14 12/03/93 DETERMINIM SAFETY

~(

PAGE FUNCTION STATUS j

WCLEAR OPERATIONS REV. 5 16 0F 21 ATTAC44ENT A-3 l

(Page 2 of 3).

7.

Operability Concern

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References (List) iOlG PR W-03d) 9.

Recommendation (Check as Applicable)

.l bQ Operable

. [- ]

Inoperable

)

10. Basis for Determination (Use Additional Sheets, if Necessary) boseel dn widtNbel dnd. ('obolbbNns !ke redwrerf i

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i beak rtnwlel em] sci /J ob $8 SW//Es kles r7ab d<m+amaec{ erou e He &uhr aa/) aide An'P<<afuec in ease / Me Aea!exebeno'ev e//ecSeenas. 74 elesgn

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a 9rk in4/ gal / ande bnps. 77Ie l9 hasa assume recsdecf pli d&v

-/<mo Au been. ih Mc / sui ro >;.

}

rk e//ecF'aprmmdly clu,Mhp Me Seafa y a s a n&,

muaf cajac i

ons<w x,c u ag a s,,,ni,,,s yy n i

anel 3

^ -/D.

DE ME#

/977AC M M 7 # W ' 0

}e

-N l

ISSUE DATE 1-EVALUATIM OPERABILITY AM N00-14 12/03/93 DETEMINIM SAFETY i C\\

FUNCTION STATUS PAGE i 'V l WCLEAR OPERATIONS REV. 5 17 0F 21 v

j A"TACHMENT A-3 j

(Page 3 of 3)

{

11. Required Actions:

'[] Execute applicable Action Statement (s) i i

i i

[] Establish immediate compensatory measures:

}

Cdi1b}wd f]p M in d (?nl C'btnida SWA E 'S f

f f

(1/1h esk (k / ortdn'V rdt/ttfs /MS kn a

v c258

bletkade, i

V i

[] Not Applicable i

12. Develop basis for continued operation:

l

[]

Internal Position for Continued Operation j

[] Discretionary Enforcement (Relief from TS)

DQ Not Applicable f

f ep $ b ff"'O Y j

13. List of paeticipants:

gj,), panot/ art Nen l$ san O d r f / / f d J ffd n *2-i hu/ f/emda fe/ Mcbll

\\

Terr 4 durbbell b Sar/ Tecbsort-Q Brmr Micc/e Chair:

Date:

/ 6[W 5500: b V!

Date:

/2 W I

NOTE: Attach copy to associated Problem Report.

P9C-I~ Yf l

aM91

l.

]

g 1

"" EMERGENCY REA ""

j-cazstanTIns N MeansIsarIca man sammum SITE NUCLEAR ENGINEERING 941322 Pa 1

l NI OR G Af.:l A TIO l

rrrr numer==

0 PtJWF MEANCWWT

@ OFEER 1

SYST3s BOUIPMENT TAG MO SWHE-1A l

1Erum e / ABSDCIRf B DOCIR erFS j

Prob Rpt$

MAR Number Vendor Manual No.

j REA Number PCN Number PEERE No.

i Procedure No.

WR Number NA IOC Number f

Calibration Data Sheet No.

Instrument Data Sheet No.

OTHERS NOD-14 ARGERMENT nearmmFIM N REQUWT DETERMINE IF THE SHWE'S WERE ABLE TO REMOVE THE DESIGN BASIS ACCIDENT HEAT LOAD WHEN SWHE-1A WAS APPROXIMATELY 60%

CLOGGED, SWHE-K WAS 30% CLOGGED, AND SWHE-lc WAS ONLY IN SERVICE ONE WEEK.\\

695 M&+

I t

i l

4 i

l O continu.a j

Arr -

i rm REIUERTS Em PLApr -NS PROVIDE TER FOLIDrING(Optional for "OTHER" Requests) l PROPOSW SOLUTIW I

f i

1 l

4 I

O coationea

}

REABOWS AND B M PROJECT EVALUATION i

THIS EVALUATION WILL BE ADDED TO THE NOD-14 OPERABILITY Pubite Relat.

Pers. Perf.

ASSESSMDrf OF THE ERAT EXCHABCERS.

Reg. Issues Reliability suc. Safety Support

)

Pers. Safety O continu.4

)

ORIGINATQE PEOME DATE i

JACKSON, G. RICHARD 240-3448 12/06/94 suPsavisonM-==

ruous DATE l

GUTHERMAN, BRIAN 231-4440 12/06 04 j

0RW AR DI RE A T0.THE F NGINEE RING

LERK" NUCLEAR ADMIN Bt0G: NA Ill j

Page 1 M i

l i

j

NM b

N

(//

j w

j am mammt SITE NUCLEAR ENGINEERING 941322 Pa et 2

l Part 2 ENGINEEPING RESOLLTION

]

Does this REA Appear to Document a "PROBtJBl* as Defined in CP-lli E NO - Coatinue to Process as an REA 1

O YES - Either Return the REA to the Originating Dept /Org for the Generation of a Probles Report, OR Generate a Problem Report. Record the Number of the PR in i

the REPGISE Block, and Return the REA to the Orginating Dept /Org.

4 l

This REA is ASSIGNED TO:

G.R. JACKSON O REJECTED BY Engineering; TOTAL WEIGHTED PRICRITY:

(For Plant Enhancement only) suruinson/unsacet smaus DATs i

AUSTIN, TERRY V 240-3660 12/06/94 masrouss l

THE GOVERNING EQUATION FOR THE HEAT EXCHANGER IS:

Q = U

A

IMFD l

THE HEAT ABSORBED (Q) BY THE SW THAT MUST BE REJECTED TO THE RW SYSTEM DURING A DESIGN BASIS ACCIDENT IS 140.38E6 BTU /HR.

i i

l THE AVAILABLE SURFACE AREA (A) OF THE HEAT EXCHANGER IS j

REDUCED FROM 8600 SQ FEET TO 6450 SQ FEET PER HEAT EXCHANGER i

FOR A TWO PASS SPLIT FLOW HEAT EXCHANGER WITH 50% OF THE f

FIRST PASS TUBES COMPLETELY CLOGGED. (50% IS USED SINCE l

THE ONE EX ONLY HAS A FEW DAYS OF SERVICE, ONE IS APPR.

j 30% CLOGGED, AND THE THIRD IS APPR. 60% CLOGGED. ALSO, THE TUBES ARE ASSUMED TO BE COMPLETELY CLOGGED EVEN THOUGH ONLY l

A PORTION OF THEIR FLOW PATH MAY BE COVERED. IN REALITY,

}

THE PERCENT OF CLOGGING IS PROBABLY MUCH LESS.)

i l

NPRDS REVIEWED:

E YES O NOT APPLICABLE

@ continued l

f f the above Response ' Disposition Recunes a '

R to be issued An EA Part 3 is Reauired orsposrTromana poconurrs j

j PR Number MAR Number Vendor Manual No.

I REA Number FCN Number PEERE No.

f Procedure No.

MR Number IOC Number Calibration Data Sheet No.

Instrument Data Sheet No, j

j i

AFrAusMsTs i

I i

4 0 continued i

j Dispositioning Organiz.4 tion

@ SNES: O NPSE: O NOE: O NCn: O Other I

^~

EEGUMEt P90Es DATs l

JACKSON, G. RICHARD 240-3448 12/06/34 l

SUPEtusW P30Ms DATs i

GUTHERMAN, BRIAN 231-4440 12/06,94 j

W REA TO THE ORIGINAT1NG DEPT (

_ m.

4 i

l.

)

E N

/

J l'

aan==--

SITE NUCLEAR ENGINEERING 941322 Pa e:

3 3 TIN #'G SHEl T Mentify tM BLOCK bemg C nt nued and Rec r d the tr f ormation '

l CONTINGRTIM FM REA PART 2 RESPONSE:

s l

BASED ON ENGINEERING JUDGEMENT AND PRESENTLY UNVERIFIED

]

CALCULATIONS, WITH THE REPORTED SHELL CLOGGING, THE RW FLOW j

WILL BE APPROXIMATELY 12,000 GPM. (THE DESIGN POINT RW FLOW IS 14,100 GPM BUT IT HAS BEEN MEASURED TO BE 15,900 GPM i

WITH AN EXCEPTIONALLY CLEAN HEAT EXCHANGER).

THE RECENT GULF WATER TEMPERATURE HAS BEEN RECORDED IN THE LOW 70'S. THUS, THE RW INLET TEMPERATURE TO THE HX CAN BE

}

CONSERVATIVELY CALLED 80 F. BASED ON THE RW FLOW, THE RW f

INLET TEMPERATURE, AND THE SYSTEM Q, ANALYSIS SHOWS THE RW OUTLET TEMPERATURE SHOULD BE APPROXIMATELY 104 F.

THROUGH A SIMILAR APPROACH, THE SW TEMPERATURES WOULD BE ON THE ORDER l

OF 144 F IN AND 110 F OUT (LIMITING CONDITION). THE CORP.ESPONDING LNrD WOULD BE 34.8 F.

APPLYING A CORRECTION i

FACTOR FOR A TWO PASS SPLIT FLOW HEAT EXCHANGER (0.965)

I REDUCES THE LWrD TO 33.6 F.

TAKING THE ABOVE INFORMATION AND SUBSTITUTING IT BACK INTO 3

FIRST EQUATION, THE MINIMUM REQUIRED OVERALL HEAT TRANSFER COEFFICIENT U CAN BE CALCULATED:

U = Q / (A

LMTD)

= (140.38E6 BTU /HR) / (6450 SQ FT

3 EACH

33.6 F)

= 216 BTU /HR FT SQ F j

PER RECENT SINGLE TUBE TESTING PERFORMED ON SITE, REFERENCE i

MOLLERUS ENGR CORP REPORT DATED 11/17/94, CR-3'S EFFECTIVE j

OVEE LL HEAT TRANSFER COEFF.CIENT WAS MEASURED TO BE AROUND j

275 BTU /HR-FT SQ-F (HIGHER THAN THE MIN. REQ'D) WHILE THE t

TESTING FLOW RATE WAS ONLY 3.44 FT PER SECOND RATHER THAN 9.15 FT PER SECOND AT THE DESIGN POINT. (HIGHER FLOW RATES j

RESULT IN HIGHER HEAT TRANSFER COEFFICIENTS. THIS IS l

CONSERVATIVE.)

{

THEREFORE, IT CAN REASONABLY BE ASSUMED THAT THE AS-FOUND l

CLOGGED CONDITION WOULD NOT HAVE PREVENTED THE SW HEAT j

EXCHANGERS FRON PERFORMING THEIR REQUIRED SAFETY FUNCTION

{

DURING A DESIGN BASIS ACCIDENT.

l i

5 THIS CONCLUSION IS VERY CONSERVATIVE SINCE IT DOES NOT j

CONSIDER THE FOLLOWING:

j

1) RW TEMPERATURE IS ~10 F LOWER THAN ASSUMED 3

2) RWP-1 DISCEARGE PRESSURE DATA INDICATES LITTLE, IF ANY REAL DECREASE IN FLOW i

l i

RaA 4 90' i

i i

I i

1 i

e,,

ggg man mamun i

SITE MX1 EAR ENGINEERING 981322 Pa et 4

l

-g3ONMJU40N SHEEI I&,t 'j the BL OCk ein. Cont nued and Rec or d the P lor m i* an e.

l 1

CONTINUhTI(M POR REA PART 2 RESPONSE:

3) THE AVAILABLE HEAT TRANSFER SURFACE AREA IS ACTUALLY l

HIGHER, SINCE ALL TUBES ARE NOT 100% BLOCKED OFF.

I J

BG NOTE: INDEPENDENT CONFIRMATION OF THE ADEQUACY OF HEAT j

TRANSFER ASSUMING THE SUBJECT CONDITIONS WAS PER-i FORMED BY A SECOND ENGINEER PRIOR TO APPROVING j

THIS REA.

REF: SOFTWARE CS94-015, M94-0056.

i i

I 4

i e

i i

4 e

k i

t 4

)

i i

4 I

i i

e 4

l 1

i I

4 REA 4 90' l

I i

4

I t

ISELE DATE EW1ATitG TEBoBILITY

D N'D 14 12/(%)/93 p

TTHMNIN3 SAEW y

PAG RfCTICN STA3tB EV.5 15 & 21 N NTIO6 M(@

9RO l

ATTAOMNT A-3 (Page 1 of 3)

OTF%BILIW EVM1%TIO4 FOM li/1,/N 1.

Initlating Individual:

$cof A Sfewar b Date:

2.

Ini t lat ing Doctrrent : PR-N C2/9 Rw Svste-A,:., d,e A e i

a >

l,.s es t v fe; lur t.S 3.

Af fected Itan (SysteTt Subsysten or C%rrponent)

Rw P; o; -

J s

4.

Systen Designat ion (s)

RW SW DC 5.

Tag renter (s)

SwAE-lAl,B,licltp brHE-IAll2 Nw - %

Rw ;9 R\\v - 33, RW 70 6.

Specified Safety Function (s) of Af fected Iten Provide coc h, - w to sw a.a oc J

re mova l o f bea f hollo wisa 9/Sle M or J

clesia n basis acc; clea f.

a s

O

j.

ISSE DATE ENNIATIPG CPEMBILi1Y f' 9g

O N'D-14 12/03/93 TTHMNitG SARIY M

v RMT, IOJ STARE REV. 5 16 7 21 M NTIOS ATT40 M N1' A-3 (Page 2 of 3) 7.

OperabiIity Concern hbien Repor b 7+-ou2 ofesc<<bes t%

occass.s I

< Jew Mic. o oP a <e %e I. e <.

k.%

J J

oPF o d Lloc k Rw flos to He DC maa co se

/

OV b'W hea b ekc NaperS.

he$owiHo on at inia J

Y c S u l h s' e CO VvoSlo d of h e ci+a.

M ay

/

)

8.

References (List)

Pn-It 4 11 A R R3 -ou ' _.27-O I 9.

Recowendation (Check as Appiicable)

[

Operable

[]

Inoperable

10. Basis for Determination (Use Additional Sheets, if Necessary)

\\

hee Yorbeb r

x.

e I

g.

NOD-14, Evaluating Operability and Determining

/~

Safety Function Status b]

10. Basis for Determination i

During the normal performance of PM-112 (DC, SW and SC Heat

. Exchanger Maintenance Inspection / Cleaning / Shooting) Mechanics j

remove any debris found in a heat exchanger and document the initial "as-found" conditions.

If liner material is-found, I

Engineering would be notified per step 4.2.1 of PM-112.

If it

]

is confirmed that a particular spool piece has lost the liner j

material, follow-up visual or UT thickness inspections are i

performed. The urethane liner is applied in various colors to help identify the location of an affected piping section if liner. material is discovered.

Since 1992, only a few small pieces of loose urethane have been found in a heat exchanger.

4 j

No piece of the urethane was larger than approximately 4" x

6".

The urethane pieces found were from spool pieces RW-26 i

and RW-28.

The number of tubes that would have flow restricted was minimal.

PR o#7 wil deleN=c a lle-= &se 61u k.J 283 1.sas 61 A4 el<y a li i-),. te.

l The MAR that justified the application of. the urethane coating was 83-06-27-01, Urethane Lining and Access Modifications for RW System.

Design Input Record Item No. 8 states "Urethane

\\

has far superior bonding characteristics to steel than PVC l

has.

It is highly abrasion resistant and therefore well 2

suited for service in the RW system.

Urethane has low water permeability which is needed to prevent corrosion of the pipe wall".

The minimal number of lining failures since 1983 help i

confirm that the urethane is well suited for use in RW system and that it adheres well to pipe surface.

In addition, there have not been any reports of large pieces of liner ending up i

in a heat exchanger.

Due to the quality control uf the i

urethane lining application, is it expected that any failure l

would be localized and would not result in full scale delamination. In the event of localized delamination, it is likely that the rubber would separate from the pipe wall and i

then tear off in small pieces from the surrounding material due to the water flow. Only minimal flow blockage would occur and that would be removed during the normal inspection &

cleaning of the heat exchanger.

A complete internal inspection of the lined piping was performed during 1990. Only one of the urethane coated pieces l

was discovered to have a

torn liner.

The - liner had delaminated in several areas, but had not come loose.

It was replaced during the same outage.

The remaining spool pieces were in good condition and provide confidence that the coating can remain intact on the pipe wall.

i-J j

+

l li II' The liner degradaticn of the four RW spool pieces addressed by

[

Problem Report 94-0268 has not resulted in.a loss.of any RW cooling flow path..

Periodic visual inspections of lined piping have identified.most liner deficiencies.

j Spool pieces RW-26 and RW-28 are on the in inlet on'SWHE-1C and SWHE-1D.

.Both M" spool pieces were discovered. with delaminated urethane at the elbow.

The~ loose section were '

removed to prevent potential flow blockage.

Both pipe l

sections are inspected monthly.

New coated spool. pieces:are-being fabricated to replace the existing ones.

RW-33 is a 24" 90 Deg elbow on the discharge side.of RWP-2B.

A 2" stub-out 11veloped a pin-hole leak during May 1994.

The leak and repair was handled in accordance with the guidance in Generic Letter 90-05.

The root cause of. the leak was embrittlement. of the lining in. only the small stub-out section.

There was no delamination or loose material associated with this piece.

RW-70 is located on the discharge of DCHE 1B heat exchanger.

Any loose piece as a result of the localized delamination, can not impact _ heat exchanger flow.

UT thickness monitoring.of the affected areas will be performed.

Replacement will cccur as required.

O~

L l

l O

ISELE DATE EW1ATM CPEfVelLi1Y d

O M D-14 12/03/93 t

i V

NTBMNifG SVE1Y PE 1

RfCTKN STAR.B EV. 5 17 OF 21 M NTIO6 ATT40MNT A-3 I

(N @ 3 of 3)

11. Required Actions:

I

[] Execute applicable Action StateTunt(s) i 4

[} Estabiish irmediate ccTpensatory (Teasures:

1 i

i i

i

~

i

[

ftt Applicable

12. Develop basis for continued operatlon:

[]

Internal Position for Continued Operation

[] Discretionary Enforcerrent (Relief frcm TS) l

[

ftt Appiicable

13. List of participants:

b001%AGC *1 L,

.h. M wes i

d>!98 Chair:

zafriM Dete: //

Date: MIo SEED:

e

'/

W PRC %.* 9f-Y4 POTE: Attach copy to associated Problen Report.

I///yk

t a

~

)

l PROBLEM REPORT PR 94 - 0268 e.,,

i l pakt 13 I;ITIATlW, MVigB. AW ISBNINIX W TM PMBLSI WWT ST TM MISI. TIES measIZATIW (1)

Title:

et System Pipivig larethans Liner Fellwes 1....

t Discoverv ; ;'-

Pr;n ration for SWSOPl

_M Ptant C.Mtian!

.^.mi Goeration

.3 n,e_,___

natae g/16/96 I The 0800

^ ^ ' ' t er t oon del Plant s mentien Auniba v mida

" ' - se (23) E g ipment Tag RW 26, RW 28, RW-70, RW 33 (21) Vender urethane Technologies Inc.(Application) &

an.

isir name!-

Technical Urethane Inc. (Manuf acture) j m Description of the Condition / Events i

Th.s RW system piping is coated with an urethane material called Tochthane 9055. The use of urethane as an acceptable RW pipe liner was provided in MAR 83 06-27-01 and the ortsinal coating was applied by Juno Insastries (now known as urethane Technologies Inc.).

Procedure PM 164 is curr9ntly in place and provides for the inspection of the RW pipingIng,sust inspection per PH 164 as well Vi as video tapi of the piping has shown liner degradation of various forms (e s.

taebl erosion, tears missing pieces-delsmination-Also, some leaks in the system ploing have occurred due to f aIlur,e of the urethane coating,. Failure could be i

che either to aproper urethane application or failure of the Tochthane itself.

The RW piping inspection program needs tighter controls to be implemented, via revision of PM-164, for the inspection, and subsequent monitoring of degraded sections, of RW piping.

Cause of liner failures and adequacy of urethane coatings needs to be determined.

J (4) Is this pretples a Radiological Safety Concern?

[xx) No

[ ] YES tamadiately contact MP S.mervisor for oraner documentation.

(s) sopirement(s) violated: NONE (e) Associated /meleted Decaments: PM 164, MAR 83 06 27 01 (7) Imiste Actions Taken:

, Contacted Urethane Vendors Recommandstians for Resolving the Prot >lem:

1) Contact vendor to determine if f ailure chas to application errors

2) Contact urethane manufacture to determine causes of urethane failures versus currently exhib8 tad signe

3) Contact other utilities who may be using urethane liners in similar applications and discuss prentems they may be encowitering

4) Based on above determine whether urethane is appropriate for application

5) Ensure adecpate trepections and subsement monitoring is in place along with appropriate corrective actions should liner fait (s) 0rigineter taant namei: Les IIerris Date: 9/15/94 y.

.riginating Department signerviser/stenager Review, DSI noview and PR CLASSIFICATICBI DETEWIIEATION:

(10) PR is

( ) a 101(na Design Basis Issus I 1 283PECTS Design Basis Issue (XXI not a Destyi Sesis Issue (11) ns mnsumaded O C'a' A # at: *W C

wTs

^==* d

neepamade M essen 7 g) Q p gq gg CAP Aseignment (if eephambiel 16L!TAE (12) originating sigsv/ seer taant a..ene (ta) Pa lasue Date:

b h - (6f,,,,,,!0 f'M [b '

/

t_2 (14)

[ ] SOTA review required G

(Deliver to SOTA and notify SStB)

~

Q(1 $0TA review NOT required.

'lE5dic~65 Net'c[MaliEr Proerems)

Z. Y"^""

/U.

9/S Sta.

W/r/ M Pmoettu nsPont TRAmeneTTro to THE nesPonesets on0AMZATioN i 1 80 Decomme

- =.

neu....

.n, nts u,,,..s.,s<o m GV CP-111 Rev. 52 Page 22

l, i

d i

)

ENCLOSURE 1 (Page 4 of 6)

PR 9_4 - 0268 Peee:_

4 ROBLEM REPORT 4

J l

PAAT 3 * $ECTIM Ats PWWLEII IGNESTIGATI(El AS CAUE ANALYSIS ?

(1) Method of Performing cause Analysis

( ) Structured Analysis (xx) Deductive Logic l

{2) CHECK ALL CAusts THAT APPt Y:

j Muman Performance

( ) Verbal Conummication

[ } Work Schedule

( ) Supervisory Methods

! ] Environmental Conditions I

[x] Written Communication

[ } Work organitation/ Planning (x) Managerial Methods

() Interf ace Design or Equipment

( ) Training / Qualification

[ } Work Practices

[ ] Change Management Condition

( ) Resource Management i

Ecuicment Perfomance

)

[x] Plant / System operation [x] Maintenance / Testing

( ) External

[ ] Design Configuration / Analysis l

[x] Equipment spec / Mfg / Construction 4

~

(3a) Primary Cause(s): There are three possible causes associated with the failure of the Tochthane 9055 coatings in the RW I

piping; improper application, material f ailure and normal service. The 2" ats out on spool RW-33 has f alted before. The v. dor stated that they have had problems in the past with application of the urethane specifically on the 2" stub outs. The bthbting and wear of the liner are both normal service life conditions. The manufacturer of Tochthane (Technical Urethanes) was contacted to discuss the various liner conditions. The vendor stated that b@bting of the urethane was caused by water permention and that it was a normal occurrence with urethans liners. The vendor said that urethane does have a defined life in this application and it depends on the fluid being piped and the conditions (temperature, pressure, etc.). The wearing as well cs the bubbling are part of that defined life. In addition, any tears that are identified are due to sharp objects (i.e.

shills) that may be in the water. The delamination of the urethane liner is being investigated as part of the corrective action 2

j plan and the appropriate steps will be taken following the determination of cause.

i 1

(3b) secondary cause(s):

j h

3 4

'(3c) Contributing Factor (s) : There are two contributing factors associated with the leaking spool piece RW-33. Inadequate resslution or felture to identify a problem (thereby having no resolution) contributed to the f atture as no actions to identify

]

and correct the problem were taken. Also, due to inadequate liner inspections (PM) urethane degradation was not identified i

until a leak had occurred. Also, there is not a program in place to more closely monitor the condition of the piping as well as 1

th2 linear if a oegraded condition is identified, thus allowing it to continue until failure.

i p) swe0RTING IuFoutATIou up APrucAato:

LER No:

l P90CEDLSE 100t 0 x PM 164 l3 WE 160::

l V NRCJVIOLATION Net:9

}

OTHER1 MAR 89-07 01 01 Jmo Ind PO FT70532v (5) muclear safety Conaespaances Analysis: N/A l

76) Previous Simitar Events / Conditions: N/A I

l (7) Manufacturer /mameplate Date: N/A i

J (8) Nonconforming Ecysipment/ Material Disposition:

[ ]N/A Ine noncentemne ewomeu er memel envwedt

[ ] Accept As-Is*

[ ] Repair *

[ ] Rework

[ } Other (describe):

Engineering Justification and Approval Required for these Dispositions (obtain documentation and attach)

(s) Maintenance Preventable Functional Failure (WFF):

[ X ] No

[ ] INITIAL

[ ] REPETITIVE Rev 3/s4 RET: Lde of Plant RESP: Quehty Preerame 901 1Sn 1 o.

)

1 I

4 1

,- g

^

REPORT PR 94 - 0268 l PROBLEM

,ses._

[?pgs46CgPenstfw Att$ess Plas (CAPP J R m %r + NNW wo<WNmseWCC mry9 w w w

' l (1) Carrective Action Plant ermsaum sa

" I f

^

CRGANI2A IVIDUAL Contact urethane coating supplier (Technical Urethane Inc.) to determine Congleted NPTS, Les Marris d coating failure can occur, life of coatings, recommendations for dternatives.

p

2. Contact urethane application vendor (Urethane Technologies Inc.) and 11/M/94 NPTS, Scot Stewart j

trrange for vendor to inspect spool RW 33 and determine cause of failure.

Olscuss other urethane liner failures (delsmination). Obtain vendor evaluate recosumendations for corrective actions.

3. Based on the vendor reccounendations obtained in step 3, review for 01/31/95 SNES J. E. Colby, per phone impact on QA inspection and acceptance procedures for urethane lined conversation 9/28 piping.

4. P rform a failure analysis of spool piece RW-33.

1/31/95

$NES, J. E. Colby, per phone conversation 9/28

5. Roccmunend needed revisions to Pu 166 considering the following: adequacy 04/30/95 NPTS, Scot Stewart af acceptance criteria; revised spool piece drawings; response to degraded or failed liners, initiate WR to monitor (UT) spools with liner failure; periodically reinspect (UT) spool; typos; enclosure; documentation.

6. Revise PM-164 to incorporate CAP #5 07/30/95 Planning, C. M. Long

7. cave replacement spool pieces for RW-16 and RW-28 f abricated (WRW 3215%

3/1/95 Scheduling, s. Moore, per

& WR 318869) conversation 9/28

8. Replace spool pieces RW-26 & RW 28 (WRs 319963 & Was to be planned) 3/1/95 Scheduling, B. Moore, per conversation 9/28

9. Perform initial UT of RW-70 elbow (WR8 321598) and periodic UT 11/30/94 Scheduling, B. Moore inspections (90 deys interval). Provide results to System Engineer.

10.. Evaluate alternative material (i.e., Tochthane products (98SS), flame 3/1/95

$NES, T. Petrowsky, per phone ay, etc.) for pipe Lining. (REA 94 1107) conversation 9/28

. Write RPA to fund inspection of RW piping ("A" DC, "B" DC, SW/RW) (See 03/31/95 NPTS, Scot Stewart

.CS 977, Control Sheet 949)

12. Review appropriate documentation and plant configuration and issue 6/1/95 NOE, 8. Gutherman, per CIDPs & DCus as necessary to have all RW spool pieces included in CMIS and conversation 9/29 j

ts revise incorrect data for existing spools.

i j

13. Evaluate results of CAP and develop additional steps if necessary.

9/30/95 NPTS, Scot Stewart 4

I (2) ADDITIONAL CAP INF M TI W:

In a discussion with Jose Gines at BG&E the subject of urethane liner failures (delsmination) was raised. He stated BC&E failure analysis of the same problem concluded that delsmination as seen on the inner portion of elbows was due to unstable flow conditions. At this point in the piping the flow is going through a cyclic action; it attaches in laminar flow to the pipe well then breaks free in turbulent flow and then reattachw. This cyclic action over time causes the layer of urethane to q

break loose eventually tearing in a sheet.

J

]

un

{3) Developed by lennt&s. ens: Les Marris Date: 09/29/94 M

i

/

i I

(4) Responsible Organization Approval by'tannt & seenit Date cM uno&do

~W 6Ar :

!F TIE PRMLEN IS QASSIFIEB' AS REPMTAALE M A TICMICAL $gdICATT(N VIE.ATit% TIEE WTAIN TIE MILLIMIW APPR&ALS l

(5) PRC:

'/

NTG No:

1 (e) DNPO:

Datet WHEN COMPLETE, TRANSMIT To StsPERv!$OR, QUALITY SYSTEMS.

3/94 REE Lfe of Ptent RESP; Quehty Preereme sol 215 12 o' d 1

1 j

CP-111 Rev. 52 Page 26 i

1

jg P.R.O B L E M REPORT PR _S4 - 0268 1

t

]

W i.

Iresserse:essattsam es,amaracar, Am 00NPumos-stammesv;TareauTv psamuss facancassummentasrtumawwrace

.I Comments:

0 CLDED N.W. 0(MIOVAll SUPWR, SITE NUCL EIIGINEERIIIS SVCS (NPSE PRI IE PERFool PROBLEM INVESTIGATION, CAUSE ANALYSIS, Am CORRECTIVE ACTION PLAll (CAP) DEVELOPIENT 5

j 1 CLDEED J. W. CAIFOELL IIGR, NUCL PLAIIT TECIINICAL RPPai i

I j

(XINTACT LRETilAME COATIIIG SLPPLIER (TEculICAL taETNANE INC.) TO DETERMIIE IIIM 00ATIIIG FAILINE CAN OCQNt, LIFE OF i

s COATIIIGS, RECGOEleATIONS FOR ALTERNATIVES 2 CPEN J. W. CAlp0 ELL NOR, IIUCL PLAlli TECNIIICAL SPPORT CGITACT tmETIIAIIE APPLICATION VElets (tstETIIANE TECIIMOLOGIES IIIC.) Ale ARRalIEE Fm WEle0R TO IIISPECT SPOOL RW-33 AND j

DETERIIIIIE CAUSE OF FAILURE. DISCUS $ OTHER URETilAIIE LIIIER FAILIBES (DELAMIIIATICII). MTAIN WEle(R EVALUATits l

l RECGeEleATIONS FOR (XIRRECTIVE ACTIONS.

3 OPEN J. E. COLBY IIGR, MUCL P-umENT ERIGINEERIIIC SERVIES l

BASED (m TIE VEle0R RECGOEleATIous OBTAINED IN STEP 3, REVIEW FOR IIFACT GI 04 INSPECTI(ul Als ACCEPTAME PRnrnu'*ES j

FtX LEETilAIIE LINED PIPIIIG.

4 OPEN J. E. COL 57 NGR, NUCL PanenENT EIIGIIIEERING SERVIES i

PERFWII A FAILIBE AllALYSIS OF SPOOL PIEE W-33.

y f

5 GPEN J. W. CAMPOELL IIGR, MUCL PLANT TECIWICAL MPPORT l

RE(XBOEIS NEEDED REVISIONS TO PII-166 CONSIDERING TIE FOLLWIIIG ADEINACY OF ACCEPTAIICE (2ITERIA; REVISED SPOOL PIEE DRAWIIIGS; RESPGISE TO DEGRADED (R FAILED LluERS, lu!TIATE na TO IEEMIT(R (UT) SPOOLS WITN LIIER FAILimE; PERItBICALLY REIIISPECT (UT) SPOOL; TYPOS; EllCLOIURE; 000SENTATION.

6 (FEN C. N. LOIIG IRACL MAINTEllAIICE WORE CGITROLS 301R REVISE PW-164 TO INCORPORATE CAP 85.

2! l I'OPEN j

3. C. IIDORE IIGR,IRACL INTEGRATED e m maging i

IIAVE REPS N MT SPOOL PIEE S FOR RW-36 AIR > RW-28 FAARICATED (na 321596 & nm 318869).

I j

8(PEN B. C.IetRE NGR, MuCL INTEGRATED erunum Iges l

REPLACE SPOOL PIEES RW-26 & RW-28 (nst 319963 & la TO BE PLAlluED).

f 9 CPEN

3. C. IIDORE IIGR, NUCL INTEGRATED SCNEDULIIIG PERFOs1 lu!TIAL UT OF RW-70 ELa0W (na 321598) Als PERI (BIC UT IIISPECTIONS (90 DAY INTERVALS). PROVIDE RESULTS TO j

SYSTEM ENGIIIEER.

I i

10 OPEN A. PETRCWIKT RAPERVIS(R, IECalANICAL/STRUCTLMAL

}

EVALUATE ALTERelATIVE MATERIAL (I. E., TECNTNANE PatBUCTS (9085), FLAME SPRAT, ETC.) FOR PIPE LINIIIG. (REA 94-1107) 11 OPEN J. W. CAMPSELL IIGR, MUCL PLANT TECINIICAL SUPPORT I

WRITE RPA TO Ftme ILSPECTION OF RW PIPIIIG ("A" DC, "O" DC, SW/RW) (SEE NOCS 977, (XINTROL SNEET 969)

?

)

12 OPEN B. (RJTNElIMAal IRACL ElIGINEERIIIG SUPERVISOR (IECN/STIIUCT)

REVIEW APPROPRIATE D003ENTAT10N Als PLANT CouFIGURATION AND ISSLE CIDPs & DCIIs AS IEEESSART TO IIAVE ALL RW SPOOL PIECES IIICLleED IN DIIS AIS TO REVISE IN CORRECT DATA FOR EXISTIIIC SPOOLS.

13 OPEN J. W. CAMPSELL IICR, MUCL PLANT TEclulICAL SUPPORT EVALUATE RESULTS OF CAP Als DEVELOP ADDITICIIAL STEPS IF IIEESSAltY.

(1) Gustity Programs Review tonnt & e>om:

Date:

l R. Nicholas 10/04/94 j

ndAi cs.; Ed Ji!

J11MM Lun m

i

+

V;.

g, EVALUATIM OPERA 8ILITY AM N00-14 12/03/93 DETERMINING SAFETY PAGE O

FUNCTION STATUS REY. 5 15 0F 21 D

NUCLEAR OPERATIOMs PRc#Il03 ATTACHMENT A-3 (Page 1 of 3)

OPERABILITY EVALUATION FORM

//

N h O- [' U/'deFI-1 Date:

1.

Initiating Individual:

l kD 031b 2.

Initiating Document:

3.

Affected Item (System, Subsystem or Component) 06 Jit?cL lOMM< OhuEk, fA S[ SAptPLE CocL&fE5',

AiCAMAL Duiv Ski /bMIP

/W4 MAL ourY iM PunP 4.

SystemDesignation(s)

Swl%D CH CA 9

5.

Tag Number (s)

$HH&lA CHHE-Id 0AHE-@

CME 5 edus- &-

.swBic + twB L 6.

Specified Safety Function (s) of Affected Item CHWE: h%cve hecd fren, cafrol Cwplex

+0 SUPPER f~ DErScnn! I mhPubl lire ne>] k,,chw,6 i

s nf Sa fe% rela te d ea u,km ed a

u <

Puc % otera;,c e,.a 3 e e n (u,,c 1.,, s yg SD If Y f 0 Of N LA Y i

ISSUE DATE EVALUATING OPERASILITY i

AS N00-14 12/03/93 c

DETERMINING SAFETY PAGE FUNCTION STATUS REV. 5 16 0F 21 j

NUCLEAR OPERATIONS 4

1 ATTACHMENT A-3 (Page 2 of 3).

J 7.

Operability Concern S/A) (ln) -l*C 5Jl.'i ct ces1poacaf5 may be idadoyade e

v f

br coinpoiseaff k perhrm Sa[eg (wckn. Das l

5

$O/1 i h't M 00 CD iO 4 li Qd. C j)[f d I /

$ $$ Ul fYe. \\ $

hr 7'echrucal Specibcab crn cav,p,went i

}

i i

8.

References (List)

E0,30 t,I22-(01) 2D80 6/1162) W-GG &cinny cqy f<nn G&

j b

NEC LWto' 3dl2RV30 N-NS9 i

i 9.

Recommendation (Check as Applicable)

] Operable i

[]

Inoperable

10. Basis for Determination (Use Additional Sheets, if Necessary)

CHHC ZT5 L.CO 3.7./2."C&EVr" does no/ address fAe-.

f f$?h Y lO$ $

0 f%

h i

!n Ccnfo-cl roce men Yored c n sh 4! bgtk ici/h no f

in SaJ l'en Je r0fya ACC.

hl.C,

0b[f(v(cl8GArkbAhl%

/

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/

O (ccrked) i

1 e viginent (Kf5, Es, v8 tTs) sv(parted Lf ci;l\\ec e, conHnves 4 he OfGRA6LE AlfTS trisfalted $ peca-Fum 0

es jo.nd kporacy vIfra. con oc flow meAer h canRem presea-t-j

'sloa. Mea.svred floa prck de.c h)k. csahdence. flou)-lo cleller.c Ef actuchem -

j j

lu.aov/d be adeguate follods) co n i

i I

PMS Sompte, coolers:

No appl. ca.ble 175 LCO ils E. C. 2. G i

lrega'es c

a.dmi,s's.s+rafve. con +cols -lo ensare k. cap.Ml<+y 4o iobhain a.nd a.nc.lg ze po bacc(Je<d SqleL.5 asple c<roleedre-s s

c.rn.nucas13 au line G4h. SQ rvy;;>l, cd., A c-fual dda. m sa.sp(<.

l ccoI4.c outle.t temperaf are u.s ob+.. led s.

parf of uir evalsc 4,m dor CAREE-g ( first, hotte st coeler).

R.civHz ind;co.+c en+,cc lO C.

^3' ~ '' " ' " "^"S "'t""' *

~

i

Norrsal dofySh)/AUpumps: Non sahG relded psamps-.<,of a ddressecl b Techanc~l.S ec,'Scdimr*

f y

I sO eVa!VA Elin h$

C CCe cCCCivVYe S VeEi$1n

,5 0.se UfCh CC50i y

"fusf ee+eJ des;p. baris <s re e

desp._baris esoe.Je4ermina+.m 40 6e l

k allow he facser evala.kan e4 <[: sac, anc'.es bekeen measu re d Re.a j

w asse nea L.

i i

l i

4 f

!O i

l i

4

)

I

31 ISSUE DATE EVALUATIM OPERASILITY i<

AM N00-14 12/03/93 DETERMINIM SAFETY PAGE

" ~ ~ ~

i FUNCTION STATUS REV. 5 17 0F 21 l

d

' l NUCLEAR OPERATIpMS i

ATTACHMENT A-3 (Page 3 of 3) 1 1

11. Required Actions:

j

[] Execute applicable Action Statement (s) i 1

l

[] Establish immediate compensatory measures:

1 1

l i

i l

i i

] Not Applicable 1

12. Develop basis for continued operation:

I

[]

Internal Position for Continued Operation 1

4

[] Discretionary Enforcement (Relief from TS)

] Not Applicable

)

13. List of participants:

I S M i a rt' f L an e.

b D. M Pccte r 8LUunder/y i

8. Go therman J l'd a s e d d '

Date: / '/'7/W dI/A14b

/

Chair:

[y [<. M 6 I U p -9 ase f

Date:

ssoo:

.i

"' ^" " ** " '" '' " * "*"*-

' " #f~ " ~ "'

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+

UNITED STATES "I

NUCLEAR REGULATORY COMMISSION 2

i i.

e f

WASHINGTON. D.C. 20066 4001

.s, l

December 20, 1993 d,,,

c.

UiE E

Clll" 7.".

I Docket No. 50-302 y

L Lw. asesp4N 4436 C.Tf=l"'

ll" u wason aie u wusseen nm j

i Mr. Percy M. Beard, Jr.

/liukutt a# AM4dNEW / //

Senior Vice President,

SUBJECT:

/ mis a /)

Nuclear Operations Florida Power Corporation FILE NO.:

'4 ai>. N 4d ATTN: Manager, Nuclear RECEIVED: '%/ / fA Licensing (NA2I)

ACT!ON DY: g, A Uz/uln t /

R Crystal River Energy Complex ptuive ee/JMist/

15760 W Power Line Street DUE DATE,

/MNEMEWAnod - V/3 b /

Crystal River, Florida 34428-6708 i

j

Dear Mr. Beard:

j

SUBJECT:

CRYSTAL RIVER UNIT 3 - ISSUANCE OF AMEN 0 MENT RE:

IMPROVED TECHNICAL SPECIFICATIONS (TAC N0. M74563)

The Commission has issued the enclosed Amendment lio 149 to Facility Operating j

License No. OPR-72 for the Crystal River Unit No. 3 Nuclear Generating Plant (CR-3). This amendment consists of changes to the Technical Specifications (TS) in response to your application dated August 25, 1989.

l This amendment replaces in its entirety the current Technical Specifications (TS) with a set of TS based on the new Babcock & Wilcox Standard Technical i

l Specifications, NUREG-1430.

l A copy of the Safety Evaluation is also enclosed.

Also enclosed is the i

Notice of Issuance which has been forwarded to the Office of the Federal l

Register for publication.

i As noted in the Safety Evaluation, an audit will be performed following j

implementation to ensure that you have established effective controls for the j

requirements that are being relocated from the existing TS to other licensee-s 1

iO 1

i

! 1 O

i We suggest that you perform your own audit to ensure controlled documents.

that the cosaiteents in your letter dated November 23, 1993 have been fully l

il i

accomplished, Sincerel,

l 4/--

c.

j Harley Silver, Senior Project Manager Project Directorate II-2 i

Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation 2

}

Enclosures:

1 1.

Amendment No. 149 to OPR-72 j

2.

Safety Evaluation 3.

Federal Reoister notice i

j cc w/ enclosures:

{

See next page l

lO~

1 1

}

1 i

I i

!O 4

i A

}

l' I O i

Two within the response time credited hn the MFW line break analysis.

valves are provided for isolation, to provide redundant isolation devices.

The staff has evaluated the above LCO adcitions and concludes that they comply with the existing Crystal River licensing basis and are therefore acceptable.

FPC has proposed not to add NUREG-1430 Specifications 3.7.11. " Control Room Emergency Air Temperature Control System;" 3.7.12 " Emergency Ventilation f

System;" and 3.7.13, " Fuel Storage Pool ifantilation System," to the improved Crystal River TS. The reasons are as follows:

Specification 3.7.11 - The temperature in the Control Complex / Control 1.

Room is maintained at a pre-determined setpoint (-70*F) during normal The Chilled Water System is relied upon to accomplish this operations.

function and also fulfills this fonction post-accident (same system configuration in both cases). A tient balance analysis was performed which showed that Control Complex heat loads are approximately the same during normal and accident operations, so that the difference between the two conditions is negligible. Based upon this line of reasoning, if j

the Chilled Water System is capable of maintaining temperature during i

i

~

steady-state operations, it is considered capable of controlling temperature post-accident. Any significant increase in Control Complex 3W

)

j temperature will be detected by the Control Roca operators well in

)

advance of approaching any real operational limit, be it equipment j

operability or operator habitability.

Specifications 3.7.12 and 3.7.13 - The Auxiliary Building Ventilation l

2.

System provides the temperature 'saintenance function of these systems at Crystal River. For Crystal River, the ventilation filtration aspect of 4

these systems is not credited as part of any accident analysis, J

q Based on the licensing basis, the accic'ent analysis, and/or deterisination of l

an adequate level of safety, and the above discussion, the staff a..cepts the l

deletion of NUREG-1430 specifications 3.7.11, 3.7.12 and 3.7.13 for the j

improved Crystal River TS.

i 2.3.8 Electrical (Section 3.8)

The licensee did not include some of the requirements of NUREG-1430, t

l The staff Section 3.8 related to certain diesel generator surveillance tests.

concludes that these specifications are outside of the Crystal River licensing j

basis, are not in the existing Crystal River TS, and that an adequate leve7 of i

safety is ensured by the existing electrical systems surveillances which are included in the improved Crystal River TS. The staff concludes that theso differences do not warrant backfitting of the NUREG-1430 surveillance i

Therefore, not including these items in the Crystal River provisions.

r

~.

Pass i Pmf 1: INTheisum, -

W IM D m m m W Tm as-smo m i

l p) Tittes PT 1M flew tetanse Innenststenstes i

as'PERTIES INTIM l

elecovery methmes WBEFI Assessment (as l

(og Ptent Canditieues normal Operation (a4 escarrense Sete 11/4/96 l Times 0900 l

tas) Ptent Leestion Guilding: NA Elevation: NA Area /Reemt NA (ae) esysipment Tag NA tar) gender j

meher(s):

Rums:

m Descrimtion of the Candition/Evneur:

Ths purpose of PT 1M is to verify that KW Loading of the emergency pump motors are within acceptable values for the dieset i

generators. The procedare also verifies that adespJete cooling water from the SW and DC systems wiLL be evellable to designated safety rotated components following an accident. There is no set fregaancy for the procedare and it is performed l

denever there is a change in the poet accident system line up or therest hydraulle analysis indicate a change is regJired.

The procedJre was last performed in Jwie of 1992 and was performed on only the SW system. Review of the test results es part of the SWs0PI Assesament has identified severet areas of concern including finst system flow belance, procedure assumptions, utilitetten of reeutts and instrument accurecies. The following outtines the verf eus areas of cancern

1) Temporary procedaret changes made daring performance of procedure are confusing,seking reeutts difficult to determine.

1

2) some of the flows are not enesured but are assumed not to have been effected since last belancing. This may teed to same i

flow being below the required Limit (QulE 1A,15).

i

3) The procedare does not acceimt for reduced flow due to pump degradation.

j

4) men ES flows that receive SW flow following en accident were not botenced. Included is incertainty whether SWV 12 flow j

should be considered. Also, flow to the RCPe was not belanced.

i

5) Instrumentation accuracy is not directly determined, rather en assimed value is used with no justification, i

6) Flow belancing results were not factored into effected calcutettons.

1 (4) la this prehtem a Radiotegical Safety CancernT C X ] NO

'- Metelv.At W -

" ear for aremar d - a tten.

I 3 YES f

(s) Respairement(s) Vieteted: none identified at this time.

j (e) ammaristad/Related Desuments: PT 136, "OC and SW Flow Isoasurements and EGDG*1 A KW Loading Due to E$ Pimps" (7; Imediate Actions Taken:

l

{

mene l

(s) secommandstlene for memotving the Prehtem

1) Regaested NCE to perform operability review of current SW system Lineup and espected post accident flow rates.

2) Further detailed review of PT 1M test results to identify all missing and suspect flow rates.

3) D:termine actunt system flew rates.

4) Factor actual system flow rates into corresponding calculations.

l

5) Revise PT 1M to incorporate resolutten of above concerns (vetidote esausptions, develop instrument accurecies, clarify l

confuelns steps, evaluate on line testing using flow modet, etc.).

j

6) Perfere PT 1M daring Refuet 10 and reeveluote for Design Basis !ssue.

7) asevolunte diesel generator KW tending.

(e) Origineter oneammals Les Norrie Date: 11/4/96 originating Department Sequervleer/Ruinger Soview, 833 Sevlew and PR CR.ASSIFICATIS BETManfles (10) Pt ist gg Yi t 1 e EERA Deal p tests lasem gg WWECTB Deales Beels Issue IIst e im Beels Issue on -

fumanumens mucLser PLent Tochnicet 7P7.b.F -" 494. u e=- e.t.: akA

a.==m-s rt Acc.g,t.d er,

- ""I""'"

T W- (_am pl:rell MIM/JE

~

CAP Assi - t es e o.:

j (12) Originatire

/94r Ipus s eqy (13) PR Issus l

Jamee E. Lane 5

(14)

()() SOTFreview roepJired (Deliver to MitA and nonify **'"1

[ ] SOTA review 1807 regutred.

isend to Directori mantity Prearmes) i M ~"

l'oM W E M c lt/WH

~

PREmSI REPERT TRAllWIITTB TO TE REWIGISISLE MEANIZATice t 3 By:

Dete/Tlas:

me.see sgT. use er mese meer memy Peeraam soe en M

p p q Nob 9 w L A n % kq.

m

l-PR0BLEN REPQRi Ph A. 0328 j

PART 2 MlW Als WWIW W TE WA

)

p) This PreMe Report fit REP WTRALE*

,a M

M Weahm R mi mes amatumus is useshof N 795 i

i A TEC3RISCat W IFICAfi m V M ATi m t

'a W

vus j

Am M D MLEAM:

,a, 50 VES 5

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sota was a met ensur a ~

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g Ra h times '4e e erroetaat. tute casirttit raaf 2 acties R. A

/skk _

PART 2 - SECTIN AZ: PLANT WITIWS AW 185EDIATE WIFICAflM BY TE MA (if raugstreal) j (i Plant Conditions:

4 mode:

RX Pla:

MWe:

RCS Temperature:

Pressure:

Occurrence Date:

Occurrence Time:

Identified Datu/ Times Oth (describe):

i (t) R Equip Avaitatte:

p) SP/Maint:

(4) Tech Spec Af ed:

]

p) Act1on Statement unmary:

d (s) Action Entry Date:

Times i

(F) Evaluate immediate Notifica on (use EM 202 if Emergency Declared) i Emergency Plan leptemented: No YES Classification 1

j (s)

Phone Ca!! R red 1

CP 111 Reference VES No Time Limit Organisation I

a. 10CFR50. 72 1 HOUR OR 4 HOUR NRC OPERAfl0NS CENTER

b. 10CFR20.1906 IMMEDIATE NRC REGION !!

c. 10CFR20.2201 IMMEDIATE NRC OPEAATIONS CENTER l

d. 10CFR20.2202 leqEDIATE OR 24 Haut IIRC OPS CENTER /DNRS i<

e. 10CFR50.36 seRC OPS CENTER i

f. NPDES PERMlf I

IATE FPC SLPERvlSOR, id4TER PROGRAMS j

R. TS 2.2.5 24 leRC OPS CENTER /FPC St.VP/MGRC l

h, j

h. EPP 24 M0ut isRC REGION !!/FPC ENVIRoseIENTAL SERVICES

{

i. ANI/FPC RISK 18eIEDI ATE NRC OPERATIONS CENTER /AN!/FPC RISC J

J. 10CFR70.52a 1 Naut NRC OPERATION CENTER j

k. 29CFR1904.8 IpeEDIATE FPC NUCLEAR SAFETT SPECIALIST l

CP-141 Reference l

a. 10CFR73.71 1 HOUR leRC OPERATIONS CENTER 1

j (s) IIOTIFICATlWS:

masE TITLE DATE/TIIE EVENT #

a. $500

\\

b. STATE

\\

c. NRC(ENS)

\\

d. NRC (REG !!)

j

\\

j

o. FTC

\\

f. DERS l

g. OTHER

\\

]

(to) a:0TIFICATION OF THE DNPO COMPLETED: I 1 TES [ ] NO Perf ormed by seems:

\\ Date:

{

(11) SOTA pan a mem:

Date & Time:

\\

N i

PART 2 - SECT 1011 B 1891 Casmuunts/RWtiens i

j

'(1) leuclear Shif t Manager (print & sign): kS kA*euf Y Date/ Time //

M i

,- T,is.ECTiON TO - D =C

. -if, A.,5 i

n Ae.

=i t. ~ ne

, e,- = sis n i

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1 1

)

l

I

?.

l '.

l ISSUE DATE EVALUATING OPERASILITY l

AND N00-14 12/03/93 DETERMINING SAFETY PAGE

,i FUNCTION STATUS REV. 5 15 0F 21

+

l lMJCLEAROPERATIONS l

PRC.# //OI A1TACHMENT A-3 4

1,Page 1 of 3) l I

OPERABILITY EVALUATION FORM 1.

Initiating Individual:

UdA

/ Date:

// f 4

W -- I N

-Mk 2.

Initiating Document:

/

3.

Affected Item (System, Subsystem or Component)

Maclecer Ternes boSed fw.[e_ be3/im [M r

i a

b SM /kg C/osec/ Gc/d Go A,n 4b581--

/lluc/h'ar-hMee.1 hc~cy kf Scq y

4.

System Designation s)

O.

i s,o dc ex/

1 l

5.

Tag Number (s)

StJf5-l A S%//M-in 5%$f- /C.

%f./A4!'-I b

'DCWE < /4 MAf-/B

)

6.

Specified Safety Function (s) of Affected Item 0mcve ConYo rnmmY be n "r o tJ bM~

/

/0 ads arth con don m ei n m

e

\\

>/~?s Cl 4 %d c A-n/po'.anA l

A ~e clese u % s c<cc<clu t a

OO ON$

f' O

4 i

3

i' ISSUE DATE EVALUATING 0PERA81LITY j

AND N00-14 12/03/93 DETERNINING SAFETY-PAGE FUNCTION STATUS lNUCLEAROPERATIONS REY. 5 16 0F 21 1

1 l!

ATTACHMENT A-3 (Page 2 of 3).

j 7.

Operability Concern l

ck,It$ aY Yp be h fXckar/e7eff e

s

}

re ws6 A

$P 3 (9M b703fS kraY f00 ConSeYfrin9 bl0 eke d' k kP3 fs-h / d 7 Q

/f oY r WebrisD art i

l 4

)

8.

References (List)

\\O Pa 960269 Pm-itn 5'A300 /srs

}

/?fw-o3a.2

A299 SP-WoA/B

\\

SP-34M/8 9.

Recommendation (Check as Applicable)

(( Operable

~

[]

Inoperable i

10. Basis for Determination (Use Additional Sheets, if Necessary)

$P P.

be r

1 i

I l

l IO 4

i I

~

i-1 1

1 ISSUE DATE l

4 EVALUATING OPERA 81LITY AM N00-14 12/03/93 j e DETERNINING SAFETY j

PAGE FUNCTION STATUS REV. 5 17 0F 21 NUCLEAR OPERATIONS 1

ATTACHMENT A-3 (Page 3 of 3) i i

l 11.

Required Actions:

1

() Execute applicable Action Statement (s)

.i l

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12. Develop basis for continued operation:

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13. List of participants:

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Chair:

Date: // /0 5500:

Date: II-/O-TY l

NOTE: At ch opy to associated Problem Report.

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g pr-w ENCLOSURE 5

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"AS-FOUND" (O

HEAT EXCHANGER CONDITION 1

l l Record the initial "as-found" conditions of the heat exchanger from Step 4.2.1 I

i l 1-What type of debris was found: (ie) barnacles, oysters, grass, etc.

a A f>e are 4 M,.

/v8B n l

i l

No l2 Estimate percent of tubes blocked by debris ie:105,25%,50% etc.

1 I

[2 6M l3 Estimate amount of debris: (ie) handfull,1/2 gallon etc.

l 1

i j4 Inspect the expansion joints for cracks, breaks, or bulges.

je-drw d,..n Eren M r.~e-c4. dn-m7 >ssA 7 w? ras; i

M I

1 l5 Visually check access door, channel head, tubes, tube sheet,. and channel i

l divider for deterioration.

Conditions:

A/c adarms/

ccmcbAcas l

l b h r e.

L d.

l I

)

I 4 ~d' l6 Note any other problem area (s):

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PM-ll2 Rev. 23 Page 14

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ENCLOSURE 5 y U r

d, "AS-FOUND" HEAT EXCHANGER CONDITION Np'&, })

I I

l Record the initial "as-found" conditions of the heat exchanger from S 1

_.i.

,1, l1 What type of debris was found: (ie) barnacles, oysters, grass, etc.7m w RaAJ4e/ES J42~ff, ew&* -

l

/

{

l etc. / EIo Estimate percent of tubes blocked by debris ie:10%,25%,50%

l2 I

8' (ie) handfull,1/2 gallon etc., 2--

l3 Estimate amount of debris:

l Inspect the expansion joints for cracks, breaks, or p es.

l4 AffER U SA$Sf9 h/

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(

I and channel Visually check access door, channel head, tubes, tube she n

l5 8M8685 5,485 i

l divider for de yteriation. Conditions:

l fY $ NE, I

I I

l6 Note any other problem area (s):

Mo/>

i l

1 l

O Page Rev. 23 PM-ll2

1 Su)ME-I C-33% b b I

, g g ENCLOSURE.5 "AS-FOUte" HEAT EXCHANGER CONDITION I

j l Record the initial "as-found" conditions of the heat exchanger from Step 4.2.1 I

l1 What type of debris was found: (ie) barnacles, oysters, grass, etc.

.BasNi>c /Es + de.c)/E i

l

/

i I

Estimate percent of tubes blocked by debris ie:10%,25%,50% etc. h l2 l

l3 Estimate amount of debris: (ie) handfull,1/2 gallon etc. / 48!

I l4 Inspect the expansion joints for cracks, breaks, or bulges.

4 AAG.</ E A S /s s.

l5 Visually check access door, channel head, tubes, tube sheet, and channel D

l divider for deterioration. Conditions:

426.34 J

C-l 19

/ 5 /ih E.

]

l I

I l6 Note any other problem area (s)-

M4 C

I I

I O

PM-11'2 Rev. 23 Page 14

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ENCLOSURE 5 "AS-FOLNW"

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j j

HEAT EXCHANGER CONDITION s.

i l

l

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l Record the initial "as-found" conditions of the heat. exchanger from Step 4.2.1 i

i l

j l1 What type of debris was found: (ie) barnacles, oysters, grass, etc. Odd e W I l

S H6LL l

l l2 Estimate percent of tubes blocked by debris ie:10%,25%,50% etc.

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I i

j l3 Estimate amount of debris: (ie) handfull,1/2 gallon etc. [u[

l I

J4 Inspect the expansion joints for cracks, breaks, or bulges.

!O i

i I

i l5 Visually check access door, channel head, tubes, tube sheet, and channel l

divider for deterioration. Conditions: [vfAr77//ed AcespTARM.

l l

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l

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I f

l6 Note any other problem area (s): (dd'# 8/isve'4

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l LJilAT LochSD LE C/L teset, l

I LO 1

PM-112 Rev. 23 Dace 9

b % M-lb 4.

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4+ Ty EllCLOSURE 5

,I,'

"AS-FOLNG" HEAT EXCHANGER CONDITION i

l l

l Record the initial."'as-found" conditions of the heat exchanger from Step 4.2.1 i

l l1 What type of debris was found: (ie barnacles oysters, grass, etc.

i 7bf/Df/r5 l

r,--

I Estimate percent of tubes blocked by debris te 10%l25%,50% etc. #8[

l2 f

l 4/[

l3 Estimate amount of debris: (ie) handfull,1/2 gallon etc.

/j I

Cd i

i l.4 Inspect the expansion joints for cracks, breaks, or bulges.

f l

1 l5 Visually check access door, channel head, tubes, tube sheet, and channel l

divider for deterioration.

Conditions:

o 8-l I

i i

I l

1 l6 Note any other problem area (s):

MMC f

l l

4 J

l 1

0 j

PM-112 Rev. 23 Page la

03Gd 1

I b d // f~ l b q 7-St./

i ENCLOSURE 5 "AS-FOUNO" j

t HEAT EXCHANGER CONDITION i

l l

l Record the initial "as-found" conditions of the heat exchanger from Step 4.2.1 l

l l

j l1 What type of debris was found: (ie) barnacles, oysters, grass, etc.

k l

oysres SdeAA j

i Estimate percent of tubes blocked by debris ie:10%,25%,50% etc. Ar.2 i,

l2 i

i 1

l3 Estimate amount of debris: (ie) handfull,1/2 gallon etc.

M'ts/Au l

1 1

Inspect the expansion joints for cracks, breaks, or bulges, d#

lOl4 1,

j l

Visually check access door, channel head, tubes, tube sheet, and channel l5 f

l divider for deterioration.

Conditions:

SA/

I I

s j

l i

I 2/v4 S l6 Note any other problem area (s):

A e en ww

)

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Page 14 i

PM-112 Rev. 23 1

UfNN$V

$gu #E-tP ENCLO5URE 5

')&

i "AS-FOUND" i

/l HEAT EXCHANGER CONDITION

._i l

l Record the initial "as-found" conditions of the heat exchanger from Step 4.2.1 l

l1 What type of debris was found: (ie) arnacles oysters, grass, etc.

l

\\lPQv l1Ybc

(

l2 Estimate percent of tubes blocked by debris'ie:10%,25%,50% etc. /es:s b /02 l3 Estimate amount of debris: (i handful,1/2 gallon etc.

l 1

O

~

Inspect the expansion joints for cracks, breaks, or bulges.

l 4 4

l l5 Visually check access door, channel head, tubes, tube sheet, and channel Ok l

divider for deterioration.

Conditions:

l l

l6 Note any other problem area (s):

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1 4

PRO 8LEM REPQRT PR 94 - 0289 d

PART 1 15tTIATim, MVIgW, Am 13sMAEM OF TM PeMLSI RepWT'sY TM ORIGINATING MgANIZATim (1) Tittet tenurrieg tem Water shast Eachanger Faultre SPPWTIM IWPtWIVIW -

faal SI

. As h Pr atten for et,ano g f2M Piune tensHtient Morumi Onoratien i

r2.i

- mee 9/13fea l 7 tem, 1400 j

2a plant '===*lan -

m a a--- *- m awn SS M tee Rom (24) Eqhsi q, Tag f jA, 15, 1C, 10 & DCHE-(af) vender.

Struthers Wells 1

(31 Demeristuen of the Canditten/ Event 4

FPC currently has e as of frequent regular heet each maintenance in otace to combat the problem of heet enchanger i

fouling and flew b in the sw system. This progree nc uses cleaning and inspecting the intake canal and RW pits; a

eteening and sheet each SW heet exchanger every 28 dayU cleaning and shooting a DC heat enchanger every ECCS systen.

il outag&ce the Level o outing.

e. These ore to esems of reducing heet exchanger fouling af ter fouling has occurred, tuut do not provide a method to re The rn eri with the fact that frequentt the fourth heet exchanger ( leen one in et mustbekacedin l

pumps to pass thefr flow surve Lance. Also at t nos the DC heet en r mus pg cleaned for j

serv n order or the j

the RWC pumps to pees the e required flow. The of the samp flow s,urveillances are to veel e capabitity of the I

pump to pass the required low and not neconsert y whether the system can pees the flow. However, the aeove steps must ee perforand so the puups can peas the requ-red Low it servet es an indicator that inodoquete preventive amintenance (with scoctfic regard to heet encharger fouling) 's tn plac,e to provide the necessary assurance that these safety related pumps ullt be able to provide doel p flow.

3 Based on system performance and unintenance there is inedespete control of the level of heet enchanger fouling.

l i

(4) Is this pret>Lem a Radielegicot safety Cancorve 00() NO j

( ) TES *

'"etely cantact 15' tw "eme for - - " itation.

i (s) Roupirement(s) Vietated: mA l

(e) Aseeciated/Related Deciamants: PR 92 0122, PM 112, NOCS 840438, PR-93 0114, Pa 92 0169 (7) tammediate Actions Takan:

NOME i

1 l

(e) Recommandations for Remotvire the Protneum:

1) Re evetuste chlorinetion of RW stgiply l

2) Utilize "ctam-tron" to control growth

3) Increase freswency of RW pit cleaning

4) Instalt strainers / filters on pump discharge

5) Identify appropriate parameters to monitor and collect data correlating it to heat exchanger fouting rates 1

6) Perform an engineering study to evaluate all options and generate a recosumendation i

7) Establish criteria for acceptable tevel of heet exchanger fouilne and sthsequent flow blockage j

8) Implement a program to monitor the effectiveness of any potential solution and revise the program as necessary l

(s) Originator tennt names: Les W. Norris Date: 9/14/94 l

Originating _._ _ tuent Siguerviser/ttenager Review, OSI Review and PR CLASSIFICATIGI DETEAMIEATIGl:

5 (10) Pt is:

I

( ) a 100 mal DesIp tesie Iseue

( ) EssPECTED DesIy tasis Iseue

()h not a Desipt Sasie Isaue (11) Remensammend M le d a,e,s I 4 [

Date: NNI che===*==

NPTS Actwted gy:

b f uj. p%gy CAP Assipriment 6#

u w.i N L}SAS j

(12) Originating sepv/ tier tennt a ent:

(13) PR leeue Date:

l M

NC. ! [. h 44.-

[C1 b

/

W (14)

(X SOTA review recpired (Deliver to EDTA and notify 353)

]

[ ] SOTA review IICT required.

(Send to Director. Gustity Proerama) os) omscTOR.auAury Dates

[

ke Q

%M[k j

PROGRAase:

MiceLEM IMPORT TMAsebaSTTED TO THE MiaPosseleLE ORGAps1ATl006 [ ] sy:

DeenTsuet Row. 3/94 RET: U6e of ment RESP: Quehty Proge 900 s I

. w aoa -

]

e ENCLOSUef 1 (Pege 2 PROBLEM REPORT PR iY - 2Gf Page: _

[ PART 2 '- SECTION Air REVIEW SY THE SOTA

/~'N

-l [

.)

(1) This Protdes Report ist REPORTASLE:

K No YES (Seetion 5 of thle attachment ie required If YES)

A TEONIICAL SPECIFICATION VIOLATION:

a NO YES AN LMPLANED #Ft F Aer W

NO YES SOTA (print & sign): N(AN4v H. d.le 3 Ch N Datenime.

9 /tr/N

v:/o IF REPORTABLE, THEN COMPLETE PART 2 - SECTION B.

l PART 2 - SECTION A2: PLANT CDWITIONS ABC IMDIATE NOTIFICATIONS BY TE SOTA (if roeptred)

(1) Plant Conditions:

Mod 2 RX PWR:

MWe:

RCS Teaq:mfature:

Pressure:

Occurrence Date:

Occurrence Time:

Identified Date/ Time:

Other (describe):

(2) Redsident Equip Available:

(3) SP/Maints (4) Tech Spec Affected (5) Actten Statement Summary:

I (6) Action Entry Date:

Time:

(7) Evaluate lamediate Notification (use EM 202 If Emergency Declared)

Emergency Plan laplemented: NO YES Classification (8)

Phone Call RecpJired CP-111 Reference YES No Time Limit Organization

[]

a. 10CFR50.72 1 HOUR OR 4 HOUR NRC OPERATIONS CENTER

b. 10CFR20.1906 IPetEDI ATE NRC REGION II (V)

c. 10CFR20.2201 IMMEDIATE WRC CPERATIONS CENTER

d. 10CFR20.2202 IMMEDIATE OR 24 HOUR NRC CPS CENTER /DHR$

e. 10CFR50.36 1 HOUR WRC OPS CENTER

f. NPDES PERMIT IMMEDIATE FPC SUPERVISOR, WATER PROGRAMS

g. TS 2.2.5 24 HOUR NRC OPS CENTER /FPC SR.VP/NCRC

h. EPP 24 HOUR NRC REGION !!/FPC ENVIRONMENTAL SERVICES

1. ANI/FPC RISK

!>#4EDIATE NRC OPERATIONS CENTER /ANI/FPC RISK

j. 10CFR70.52a 1 HCUR NRC CPERATION CENTER

k. 29CFR1904.8 IMMEDIATE FPC NUCLEAR SAFETY SFECIALIST 4

CP-141 Reference

a. 10CFR73.71 1 NOUR NRC OPERATIONS CENTER j

(9) NOTIFICATIONS:

mAME TITLE DATE/ TIM!

EVENT #

a. SSCD j

b. STATE

c. NRC(ENS) 4

d. NRC (REG II)

e. FPC

f. DHR$

g. OTHER (10) NOTIFICATION OF THE DNPO COMPLETED: ( ) YES ( ) NO Performed by (Initial):

Date:

(11) SOTA (print & sign):

Date & Time:

l PART 2 - SECTION B EsM Ccuments/ Recommendations q

(1) Nuclear Shif t Manager (print & sign):

DJte/ Time:

FORWARD TNIS SECTION TO TNE DIRECTOR, QUALITT PROGRAMS Rev. 3/94 RET: Life of Plant RESP Quality Programs 900 07. (1 e

~

!s 1

f 1

l

=~

il

!(

i ENCLOSURE 1 (Pese 4 of (

PROBLEM REPORT PR R4 - 0269 r.w_

l

pMF!SMM Ast em INSTIGA11em MMNRSMHa*MWcMiWWEPGruusWMWWW Memp * #at (1) method of Perfeming Cause Analysles

! 3 Structured Analysis

[XX) De& active Logic j

(2) oMECK ALL Causse THAT ApptY:

i thman Performance i

! 3 verbel Casumication

( 3 Work Schedule

[ ] Supervisory methods

[ ] Environmental Conditions j

( ) Written Commwilcation

( 3 Work organization / Planning

[m] Manager al methods t 3 Interface Design or Egalpment j

( 3 Trainins/euellfication [ ] Work Practices t ] Change maneggment Condition j

! ] Resource Management j

EmJimment Performance l

[ ] Plant / System Operation Ix) Maintenance / Testing

( ) External I ] Design Configuration / Analysis l

t 1 EspJipment Spec /Mfs/ Construction i

(ae) Primary cause(s): The primary cause of heet enchanger fouling is ese to mortne growth in the intake, flumes and RW pits.

1 This problem has been previously identified and some effort to reduce the enomt of fouling has been taiderteken via j

laptementation of a program of regular cleaning and inspection of the RW pump intake and suction pit. Newever, as the problem report states, this cleaning and inspecting along with NX PN's attempts to control the probles after growth and fouling have a

j occurred. In addition, the programm in place mey be insufficient to ensure that the level of fouling is maintained within i

acceptable mergins to ensure system operability. An area of concern that has not been fully addressed is the RW pit itself.

j Fouting of a DC heet enchanger has been documented in the past. Of concern is that this NX does not norimetty have flow and after being ahet and cleaned per PM 112 is left in wet toy w with domin water. As such, any blockage that prevents sufficient l

pulp flow from being obtained is intro &ced at the time the survelltance is performed. Since the flow rate of the DC/RW pump is i

less than RWP 1, complete NX fouling h e to additionet debris coming off the wells is unlikely. Thorwfore, it is concluded that this sudden surge of debris resulting in heet exchanger fouting anJat also be coming from the loose debris in the RW pit floor.

l' This, validates the conclusion that MX fouling is ese to marine growth coming loose frein the walls of the intake systen and 1

lltustrates the complealty of the problem associated with NX fouling. The concern over NX fouling and flow blockage within the l

RW system is a well recognized problem by both the industry and the NRC, and additionet work needs to be done in this area to ensure the our comunitaant to Generic Letter 8913 is adequetety met.

(3b) Secondary cause(s): A secondary cause to heat exchanger fouting is that elimination of the source has not occurred. Rather sll the steps implemented thus for are an attempt to control the problem once it has already occurred. Therefore, en adequate i

solution to correct the

root cause* of the SW and DC MX fouling problems has not been developed. The are numerous possible salutions to the problem and it may be that the most appropriate solution, due to the various factors surrounding the problem, i

1 is a combination of several control and eliminetton technimaes.

s j

(3c) Centributies Facter(s) :

i l

4 (4) EsupmTIus IsF0MATION nr AppucAats):

l m L MisegwAg h pacCalMB;4e:W lG LWa GetM2 bMRC'W10LAftgN150tW KOTERWah f

(5) aucteer Sofety Cemespances Anotysis N/A (6) Previous Simiter Events / Conditions: N/A i

(D Manufacturer /Weemplete Deta: N/A 6

l (s) menconforming EspJipment/Noteriet Disposition:

i

( ]N/A ino u m ecomet er metensi inweewee

[ ] Accept-As Is*

t 1 Repelr*

I ] Rework j

[ } Other (describe):

Engineerirg Justification and Approval Required for these Dispositions (obtain documentation and attach)

(s) nsintenance Proventatdo Ftsictional Falture (ISTF):

I

( ) No I ] INITIAL

!X1 REPETITIVE d

Row: 3/s4 RET: Lsfe of Mont RESP: Quehty Presseme 301 19811 of 21 1

il*

ENCLOEURE 1 (Pese 5 of e.

j

i:

i i

PROBLEM REPORT PR 94 - 0269 Poe.:_

W een eu Ammy

ppEthME N Astlers Ptar(CAP)e ^'~ w M 23 v

d (1) Corrective Action Plant "P"8" 88 gggge ACTim8 IM msANIZATI(ul/ISIVIOu4L l

1. Include the RW system in the existing biofouting study (90 07 07-00),

6/1/95 Not, s. Gutherman, per phone l

1 dich is evaluating methods for controtting marine biofouting (i.e.,

conversation 9/28 I

l thermal, chemical, protective coatings, chtorine, filter / strainer at pump discharge, Clem-trol etc.)

2. Develop a RW system operability curve that will allow NX operability (as 5/31/95 NoE, 8. Gutherman, per phone i

determined by its ability to dissipate heat) to be determined based on a conversation 9/28 i

actunt UNS temperature, RW system flow, and NX delta P. (see CAA N 90-024-43)

3. Review SP 300 RWP discharge pump pressure acceptance range as indication 1/30/95 NPTS, Scot Stewart i

af heet exchanger fouling and subsegeant action in the event the range is uceeded. (REA 94 1093)

I

4. Contact seaward Marine services to determine the builde of marine Completed NPTS, Les Harris 4

growth in the RW pits free W to 9R.

a

5. Review WR history to determine the number of NX fouting events that have 3/15/95 NPts, Scot stewart i

occurred between the may 1993 ( M ) recire line fouling PR and the 4/94 (98) j fluxe cleanig.

j

6. Revise SP 300 RWP 1 discharge pressure bend to reduce fouting 4/15/95 Operations, Greg Natnen, per

]

accumulation between weekly cleanings, per CAP g3.

telecon 9/28

7. Have Divers inspect the condition of the "B" RW pit based on results of 8/15/95 schedating, B. Moore, per CAP e5 and g3.

conversation 9/29

8. Obtain SWNE dette-P data for trending.

11/30/95 NPTS, Scot Stewart q

I

9. Send IOC to operations regaesting notification of the system engineer in 11/31/94 NPTS, Scot Stewart the event the DC heet exchanger must be cleaned and/or the clean SW heet o changer is ptoced in service before RW pumps can achieve the required I

flow.

i

10. Perform a calculation to determine the number of MX tubes that may be 4/30/95 NCE, S. Gutherman, per phone i

plugged or partially blocked and the MX still be capable of removing the conversation 9/29 8

necessary heet.

11. Evaluate the over att adequacy of thw NX flow blockage prevention and 10/1/93 NPTS, Scot Stewart j

steps within this CAP for acceptability in controlling MX fouling and flow i

btockege. Establish addltioneL Corroctive Actions as necessary.

t i

(2) ADDITIONAL CAP INN at4 TION:

i i

A s

(3) Developed by want a s.yq: Les Harris T* l Date: 9/29/94 (4) Reaperuible organizetten Approval by want a s.yq:

[

Date:

Y lAYN A',

0 V j

IF TW PSEEMIS CLASSIFIS AS REpWTAALE W A TEMIC$C WIFICAT!W VllRRim, TIBI WTAtt TM MELWING APPROVAL 5 l

3 (1) PRC

/

MTG mo 1

i l

(e) DWO Dates l

l i

WNEN COMPLETE, TRANSMIT TO SUPERVISOR, QUALITY SYSTEMS.

)

Rev: 3/s4 RET: Lite of Plant RESP: Quakty Pre reme sol 215 ?e2 t

4 i

i CP-111 Rev. 52 Page 26

p PR 94 - 0322 y' 1-PROBLEM REPORT w

6 I

PART 1: INITIATIW, MVIEW, AS ISSIANN OF TIE POWLBI REPWT ST TE WIGluATIMB WGANIZATIM l

(1)

Title:

Lack of Proper Operability Assessment 1j_

RPPW ilus INF W IAT13 j

(21) Discovery leethod:

SW/RW/DC Setf Assessment j

(2s) Plant Condition:

Power Operation j

(21) Occurrence Date:

11/09/94 l Times 1300 l

l (2d) Plant Location:

Building: NA Elevation: NA Area / Room: NA j

(21) Egalpment Tag NA (21) Vendor Ihadier(s):

Names i

i (3) Description of the conditierVEvent:

)

i During the course of the SW/RW/DC Self Assessment it was discovered that conditions exist or have existed for which an operability assessment should have been performed, and was not docunented. Examples of this can be found in PR-92-0122, l

" Fouling of DC Heat Exchanger with Marine organisms", PR 93 0114 "High Pressure Discharge on RWP-38 Revyjers the 8 OMR System l

Inoperable", PR 94 0269 " Recurring RW Heat Exchanger Fouling" PR 94-0320 "PT 136 Flow Selance inconsistencies for KW Loading

)

j of the Emergency Diesel Generators.

I i

4 f

i n

i j

(4) is this protdem a Radiological Safety Concern?

i (x) No i

( 1 YES Insdiately contact IIP Sunervisor for aromer documentation.

s l

(5) Recpairement(s) violated: CP 111, NOD-16 (e) Associated /Related Documents: NA (7) IMiste Actions Taken:

Operability Assessment of PR-94 0320 was performed IAW N00 14

}

t i

?

i l

(e) Recomendations for Resolvin0 the Proidae:

l Ensure responsible personnel are knowledgeable of the requirements of CP 111 and N00-14.

9) Originator tonnt names: R. A. "ae res/

Date:

Originating Department $spervisor/Nonager Review, 081 Review and PR CLASSIFICATICNI DETERMINATICBI j

(10) PR is:

)

( ) e KIItnal Desipi Basis issue

( ) RfSPECTED Desi p Basis Issue (x) Not a Desi p Basis issus (11) -

NPTS Accepted By:

Oste

...... :t-"**""1 neepensees seenseer.

J.W. Campbell CAP Assigrunent t.f essi.catsel:

i (12) Originatitie $sgsv/ leer tennt a..oni:

(13) PR Issue Date:

I (14)

[ ] SOTA review required (Deliver to SOTA and no'tify SSIE)

{

[ ] SOTA review NOT required.

ijg g.Jg Director euelity Promrams)

(15) osRECTOR,QUAUTY Dete:

onOOAAtes:

PRWLEN REPORT TRANWIITTED TO THE RESPONSIBLE ORGANIZATION (

)

By:

Date/ Times Rev. 3/s4 RET: L.fo of Plant RESP: Quehty Prog em 900 973 j

i 1

1

-

ML20078A397

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