ML20238D729

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Responds to NRC Bulletin 87-001 Re Plant Pipe Wall Thinning Concerning Codes or Stds for Which Piping Designed & Fabricated.All Mods & Repairs Made in Accordance W/Original Design Codes or Later Code Editions
ML20238D729
Person / Time
Site: Farley  Southern Nuclear icon.png
Issue date: 09/08/1987
From: Mcdonald R
ALABAMA POWER CO.
To:
NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
References
IEB-87-001, IEB-87-1, NUDOCS 8709110358
Download: ML20238D729 (23)
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$a Alabama Power Company 600 North 18th Street Post Office Box 2641 Birmingaam, Alabama 35291-0400 i Te'ephone 2 cts 250105  ;

L LOXce"Leni Alabama Power the Southem electnc sys*em i

September 8, 1987 Docket Nos. 50-348 10CFR50.54 50-364 U. S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, D. C. 20555 Gentlemen:

Joseph M. Farley Nuclear Plant Units 1 & 2 Response to NRC Bulletin 87-01 In response to NRC Bulletin No. 87-01: Thinning of Pipe Walls in Nuclear Power Plants, the following information is provided for the actions requested:

NRC Question:

1. Identify the codes or standards to which the piping was designed and f abri cated.

APCo Answer:

The design, materials, fabrication, irsstallation, examination, testing and stamping of the nuclear piping was in accordance with the ASME Boiler and Pressure Yessel Code,Section III,1971. Nuclear Power Plant Components, including all Addenda thru Summer 1971. For the conventional steam and service piping, the Code for Power Piping, ANSI B31.1.0,1967 applied to the original design, materials, fabrication, examination and testing. All modifications and repairs have been made in accordance with the original design codes or later editions and addenda of these codes.

NRC Question:

2. Describe the scope and extent of your programs for ensuring that pipe wall thicknesses are not reduced below the minimum allowable thickness.

Include in the description the criteria that you have established for:

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U. S. Nuclear Regulatory Commission Page 2 September 8, 1987

a. selecting points at which to make thickness measurements
b. determining how frequently to make' thickness measurements
c. selecting the methods used to make thickness measurements
d. making replacement / repair decisions APCo Answer:

From January,1983 to January,1987, the scope of piping inspections for erosion / corrosion included high energy two phase flow (wet steam) piping and locations where hot water flashed to steam due to a pressure drop.

During the first quarter of 1987, inspections were conducted on single phase flow piping during a short outage on Unit 2, and at power on Unit 1.

All locations to date have been on the secondary system piping. Past programs have concentrated on carbon steel wet steam piping, although there hsve been inspections on a few components in stainless steel lines, dry steam lines, and liquid single phase flow, even before January,1987.

A listing of the piping inspections for both units includes the foll owing:

Date _ Unit Outage 1/83 1 4th Refueling 2/84 1 5th Refueling 4/85 1 6th Refueling

)

10/86 1 7th Refueling 2/87 1 N/A (At Power) 9/83 2 2nd Refueling 1/85 2 3rd Refueling 4/86 2 4th Refueling ,

1/87 2 Maintenance '

a. The criteria for prioritizing systens prior to the issuance of EPRI NP-3944 was based on velocity and moisture content. Components within these systems were selected based on engineering judgement and I knowledge of failures in other plants. )

)

Starting with the Unit 16th refueling outage, the configuration factors from NP-3944 were used, again with engineering judgement, knowledge of failures at other plants, and experience gained from previous inspections. Systems known to be more severely affected j were inspected more thoroughly; i.e., more components were inspected. j For the Unit 2 fourth refueling outage, an-outside contractor, Technicon Enterprises, Inc. (TEI) was hired to develop a new '

} program. TEI recommended the systems and components based on the inspection guidelines set forth in EPRI Report NP-3944.

1

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U. 'S. Nuclear. Regulatory Commission Page:3-September 8, 1987-

-The'information gained from working ~ with TEI was incorporated'into subsequent inspection plans, :along with plant-specific experience, to select the systems and. components to-be inspected.

Inspections were performed on- the Feed Pump suction piping in early 1987, after the failure at Surry Unit 2. The Unit 2 inspections w!re

. completed during a 'short _ maintenance outage. Ten fittings were'

' inspected, based on the ten worst-case geometries per EPRI NP-3944.

The Unit 1 inspections. were performed at. power, and three fittings were chosen based on the three-components found on Unit 2 which had the least . remaining life cycles.

b. -Inspections at Farley Nuclear Plant are not performed'on thel basis of '(

a fixed frequency. When a component is inspected, a wear rate and remaining;11fe (to code minimum allowable wall thickness) are calculated, and. reinspection is recommended, where appropriate, for a specified future outage.. Normally, reinspection is recommended when half the remaining life of the component is predicted to occur. It is Alabama Power Company's judgement that this method ensures that the component will not fail prior to its predicted end of life, and h reduces the number of repetitive inspections.

c. Components are marked with a complete scan grid system and basic thickness measurements are made using digital and/or conventional' manual ultrasonic instruments. A procedure is utilized for the layout of grids and recording data to ensure complete replication.

The use of automatic ultrasonic scanners is being implemented where practical in lieu of manual techniques.

l' l d.. Replacements / repairs are made wherever thickness measurements do not meet the acceptance criteria. This criteria (which meets the EPRI Guidelines) requires that the nominal pipe thickness less measured wear must exceed the minimum code allowable thickness plus the wear expected during the next cycle (approximately 16 months) plus 10%.

NRC Question:

3. For liauid-phase systems, state specifically whether the following l factors .have been considered in establishing your criteria for selecting-L points at whi;h to monitor piping thickness (Item 2a):
a. piping' material (e.g. , chromium content)
b. piping configuration (e.g., fittings less than 10 pipe diameters apart)
c. pH of water in the system (e.g., pH less than 10)
d. . system temperature (e.g. , between 190 and 500"F)
e. fluid bulk velocity (e.g., greater than 10 ft/s)
f. oxygen content in the system (e.g., oxygen content less than 50 ppb)

a U. S.' Nuclear Regulatory Commission ~

Page 4 September 8, 1987 .

APCo' Answer:

3. . a. - ' Piping material-; chemistry i_s known only to the. extent of the ASTM or 4

ASME specification to which the piping was supplied. Information on carbon steel piping for residual elements such as chromium and copper conteW are not available. Consequently, the selection criteria for new systems.and components only addresses' material types (i.e.,

. stainless,- carbon, or. chrome-moly).

b. Piping configuration is a vital' consideration in the selection of.

components to be inspected. The configuration factors of.EPRI NP-3944 are used, with special consideration given to closeiy spaced fittings, control valves, and other special . cases.'

c. pH has not been considered in the selection criteria. It is assumed to be essentially constant for wear . rate throughout the . secondary system,- therefore any effects would be the same on all components.
d. The system temperature is a factor which is considered in the selection criteria. EPRI NP-3944 gives a graph of temperature vs.- -

temperature factor. This temperature' factor is one input to Keller's equation, which was published in NP-3944 and is a primary tool for predicting erosion rates.

e. Bulk fluid velocity is a critical factor in the estimation of wear rates and is considered. It is.particularly important in comparing various portions. of the same system.
f. Oxygen content is not considered in the selection criteria. As with pH, it is assumed to be constant for wear rate throughout the

. secondary system, and therefore to have equal effect on all-l compcnents.

It should be noted that the above factors are only important for estimating erosion rates.for systems and components. Once actual measurements are taken, the estimates of erosion rates are redundant, and of considerably less importance.

NRC Question:

4. Chronologically list and summarize the results of all inspections that J have been performed, which were specifically conducted for the purpose of o identifying pipe wall thinning, whether or not pipe wall thinning was discovered, and any other inspections where pipe wall thinning was discovered even though that was not the purpose of that inspection.
a. Briefly describe the inspection program and indicate whether it was specifically intended to measure wall thickness or whether wall thickness measurements were an incidental detenrdnation.

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.U.~ S. Nuclear Regulatory-Commission Page 5 o ,

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b. Describe what piping was examined and how (e.g., describe the -

Reinspection instrument (s), test method, reference thickness, locations .

examined, means for locating measurement ' point (s) in subsequent y,

' inspections);

g c. Report thicknes: measurement results and note those that were.

identified at ' unacceptable and why.

Id. .-Describe actisns alreacly taken or planned for piping that has: been found to have a nonconforming wall thickness. If you have performed -

a failure analysis, include the results of that analysis. . Indicate ~

whether the actions involve repair or replacement, including a'ny change of ' materials' .

APCo Answer:

1

4. A brief description of each inspection and a. chronological listing of the-results are included in theLfollowing responses:
a. -All of the FNP inspection' programs were specifically intended to-measure pipe wall thicknesses.

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b. The response to question 2c addresses the means for locating

. measurement points -in subsequent inspections. These inspections

~ include:

' Unit 1 The Unit 14th Refueling Outage Inspection was performed in January 1983 using a ' digital ultrasonic thickness gauge calibrated with a step block. The inspection was performed on the intersection' points.

of two inch to six inch grids (depending on pipe size) and the entire fitting, plus'ene foot upstream and downstream was inspected. Items inspected which have a program item identity are shown in Table I.

The Minimum Acceptable Thickness column in this table identifies when a- detailed remaining' life' evaluation is necessary. No repairs or replacements were required.

The- Unit 15th refueling outage inspection was performed in February of 1984 in the same manner as the Unit 14th refueling outage. Items

. inspected'are shown in Table I. No repairs or replacements were requi red.

The Unit 16th refueling outage inspection was performed in April of

' 1985 in the same manner as the Unit 14th refueling outage. Five components on the cold raheat piping were inspected from the inside surface of the pipe. The items inspected are shown in Table I and the items which did not meet the acceptance criteria are shown in Table II.

U. S. Nuclear Regulatory Commission Page 5 September 8, 1987 The Unit 17th refueling outage inspection was performed in October of 1986 in the same manner as the Unit 14th refueling outage, but on a reduced grid size of one to two inches, depending on pipe size, in the susceptible areas of the component. The items inspected are shown in Table I and the items which did not meet the acceptance criteria are shown in Table II.

The Unit 1 feed pump suction piping was inspected in February of

-1987. These inspections were performed at power and three fittings were chosen for inspection based on the corresponding components found on Unit 2 with the least remaining life cycles. The inspections were made using a conventional ultrasonic instrument calibrated with a steel step block. Measurements were taken at the  !

intersection points of 4 inch grids in the susceptible areas of the components. The items inspected are shown in Table I. All of these )

items met the acceptance criteria. j Unit 2 .

The Unit 2 2nd refueling outage inspection was performed in September of 1983. These inspections were performed in the same manner as the Unit 14th refueling outage. The items inspected are shown in Table I and the items which did not meet the acceptance criteria are shown l in Table II.

1 The Unit 2 3rd refueling outage inspection was performed in Jauary l of 1985. These inspections were performed in the same manner as the '

Unit 14th refueling outage, however eight items on the cold reheat j piping were inspected from the inside of the pipe. The items inspected are shown in Table I and the items which did not meet the acceptance criteria are shown in Table II.

The Unit 2 4th refueling outage inspection was performed in April of 1986. Technicon Enterprises Inc., (TEI) was contracted to develop an inspection program for this cutage. Ten fittings were inspected with automatic scanning and the remainder were inspected manually using conventional ultrasonic instruments and a 1 inch grid. For the manual inspections, 120 degrees in the most susceptible area and 45 degrees along the bottom of each component, plus 10 inches of downstream piping were inspected. The items inspected are shown in Table I and the items which did not meet the acceptance criteria are shown in Table II.

The Unit 2 feed pump suction piping was inspected in January,1987.

Ten fittings were inspected, based on the ten worst-case geometries per EPRI NP-3944. Inspections were performed using a digital ultrasonic thickness gauge on the intersection points of four inch grids in the susceptible areas of the components. The items inspected are shown in Table I. All of these items met the acceptance criteria.

. k U. S. Nuclear Regulatory Commission Page 7 September 8, 1987

c. All thickness measurement results for the fittings found to be unacceptable e.re shown in Table II. These items did not meet the acceptance criteria. j
d. Actions taken for nonconforming wall thicknesses are shown in Table III.

i NRC Question:-

5. Describe any plans either for revising the present or for developing new or additional programs for monitoring pipe wall thickness.

APCo Answer:

Alabama Power Company. is developing new erosion / corrosion programs for both units which will be in effect by the next outage on each unit.

These new programs will allow cost-effective scheduling of inspections and piping replacement, and apply to single-phase and two-phase erosion / corrosion.

The planned inspections for the next outage on each unit will be performed by automated scanning equipment where practical, and manually using conventional ultrasonic instruments in other locations. In either case, the entire surface of each component will be scanned to ensure that the minimum thickness is located.

The criteria for selection of systems for this program include:

i

1. Carbon steel . piping systems which contain steam or 200-500*F l water, and for which Keller's equation (from EPRI NP-3944) predicts that erosion is likely.
2. Systems which have been found to be eroded / corroded in previous pipe thinning inspections.

1

3. Piping systems which are similar to systems which have experienced i erosion / corrosion at other plants.

The criteria for selection of components within these systems include:

1. They are a configuration for-which Keller's equation predicts erosion.
2. Previous inspection data indicates that the component has experienced erosion in the past.

a

V. S. Nuclear Regulatory Commission page 8 September 8, 1987

3. Inspection data indicates that similar components have experienced erosion.

4 Inspection data. indicates that components upstream or downstream have experienced erosion.

5. They are similar to components which have exhibited erosion in other plants.
6. Some components may be selected on a random basis.

The preceding information represents Alabama Power Company's current or proposed program related to this issue. The current or proposed program may be changed as deemed necessary. Information related to.this issue is t available onsite for.NRC review. If there are any questions please advise.

Respectfully submitted, ALABAMA PO E COMPANY f / ,

R. P. Mcdonald e

RPM / CDP:cs1-1 Attachments cc: Mr. L. B. Long SWORN TO AND SUBSCRIBED BEFORE ME Dr. J. N. Grace Mr. E. A. Reeves THIS p rA. DAY OF .Venenax , 1987 Mr. W. H. Bradford f slt lAl-i Mr

' Notay 'Fubl i'c '

My . Commission Expires: /0 7 7 l I

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bc: Mr.-W. O. Wh'*tt.

Mr. W. G. Hairston; III Mr. K. W. McCrackee Mr. J. D. Wootard Mr. J. W. McGowan (

Mr. C. D. Nesb'Itt Mr. R. G. Berrybill Mr. D. E. Mansfield ,

Mr. J. G. Sims "

Mr. J. A. Ripple Mr. J. K. Osterholtz Mr. J. T. Brantley Mr. D. E. Dutton Mr. J. R. Crane Mr. T. N. Epps Mr.- K. C. Gandhi v I

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TABLE I INSPECTION ITEM DESCRIPTION  !

l Unit 1 4th Refueling Outage Minimum Program Acceptable Item System Description Thickness

2. Extr. Stm. to LP Heater 5 16" Elbow .354
3. Extr. Stm. to LP Heater 5 24" x 16" Reducing Tee .484/.354
8. HP. Stm. to MSR 14" Elbow .354 ,
9. HP. Stm. to MSR 14" x 8" Reducer & Y Branch .313/.227
10. HP. Stm. to MSR 8" 45 Elbow .227
11. HP. Stm. to MSR 6" Elbow .200
14. HP. Stm. to MSR 8" Pipe Bend .227 j
19. Extr. Stm. to H.P. Htr. 16" x 12" Red Tee & Elbow .354/.288  !

(6A & 68)  ;

20. Extr. Stm. to H.P. Htr. 12" Pipe Bend .288 l (6A & 6B) i
21. MSR Shell Drains 14" 45* Elbow .251
24. MSR Shell Drains 12" Elbow .315
25. MSR 2nd Stage Drains 12" Elbow .315
26. MSR 2nd Stage Drains 12" Tee .315
28. MSR 2nd Stage Drains 12" Elbow .315
31. MSR 2nd Stage Drains 14" Pipe l' Downstream .251 of V536B
33. MSR-181st Stage Drains 12" Pipe l' Downstream .248 V542A
36. MSR Shell Drain Tank 6" Tee .200
37. MSR Shell Drain Tank 8" x 6" reducer .230/.221
39. 2nd Stage MSR Startup 3" Elbow .208

& Excess Stm. Vents

42. 2nd Stage KSR Startup & Z" Elbow .157 Excess Stm. Vents
43. 2nd Stage MSR Startup & 3" Elbow .208 Excess Stm. Vents
44. MSR Cross Under Piping Manhole in 37-1/2 Pipe .571
45. MSR Cross Under Piping 37-1/2 Elbow .571
50. MSR Cross Over Piping 37-1/2 Elbow .571
51. Main Steam Drains 2" x 1" Reducing Tee .157
53. Main Steam Drains 2" Tee .157
56. Main Steam Drains 2" Elbow-l' Downstream .157 of Control Valve
58. Ext. Stm. Drains for 2" Pipe-l' Downstream of .117 Htrs. 4, 5, 6 Ori fice
59. Ext. Stm. Drains for 2" Elbow-l' Downstream of .112 Htrs. 4, 5, 6 V576

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TABLE I INSPECT $00ITEMDESCRIPTION Unit 1 4th Refueling Outage-  !

Minimum Program ., Acceptable Item System Description Thickness 60, Ext. Stm. Drains for 2" Pipe-5' Downstream of .112 Htrs. 4, 5, 6 .

V574

61. MSR Cross Under Piping Reducer  ; . 571
63. Htr. Drains from LP 12" x 4" Reducer Tee and .246 Htrs. 3 & 4 Blind Flange ,
64. Htr. Drains from LP 8" x 3" Reducer and .211 Htrs. 3 & 4 Drain Connection i
68. Htrs. 5 & 6 Drains to 16" Elbow .300  !

Htr. Drain Tank & Pump

70. Htrs. 5 & 6 Drains to 12% Reducer

.300.

Htr. Drain Tank & Pump ,

Unit 15th Refueling Outage

1. Extr. Stm. to LP lleater 5 316" Elbow _ .354
2. Extr. Stm. to LP Heater 5 20" 45' Elbow .419
3. Extr. Stm. to LP Heater 5 20" Elbes .419 4 Extr. Stm. to MSR 1st Stage 14" Elbow .354
6. Extr. Stn. to MSR ist Stage 8" 45" Elbow .227
6. Extr. Stm. to MSR 1st Stage 8" Pipe; Bend .227 ,
7. Extr. Stm. to MSR 1st Stage 8" Pipe Bend .227
8. Extr. Stm. to MSR 1st Stage 8" 45" Elbow .227
9. Extr. Stm. to HP Heater 6 16" x 12" Reducer Tee & Elbow .354/.208
10. Extr. Stm. to HP Heater 6 12" Pipe Bend ' .288
11. Extr. Stm. to HP Heater 6 16" Eibow .354
12. MSR Shell Drains 12" Elbow .315
13. MSR Shell Drains 10" Pipe Eend .261
14. MSR 2nd Stage Drains 12' Tee .315
15. MSR 2nd Stage Drains 12" Elbow .315
16. MSR 2nd Stage Drains 8" Elbow .300
17. MSR 1st Stage Drains 12" Pipe-1' Downstream V542A .248
18. MSR ist Stage Drains 6" Pipe Bend .200
19. Heater Drain Tank Vents 8" x 6" Red. .230/.221
20. Heater Drain Tank Vents 8" Elbow

.230

21. MSR 2nd Stage Excess Stm. 3" Elbow .208
22. MSR 2nd Stage Excess Stm. 3" 45' Elboa .208
23. MSR 2nd Stage Excess Stm, 3" Elbow .208
24. MSR Cross Under Piping 37-1/2" Elbow .571
25. MSR Cross Under Piping Expansion Joint .571 1

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n TABLE I INSPECTION ITEM DESCRIPTION p,

. Unit 1 5th Refueling Outage I

Minimum Program .i- Acceptable Item System Description Thickness 4 26. Main Steam Line Drains 2" Elbow-1' Downstream.of .157 Control Valve

> +

27. Mair Steam Line Drains 1st Bend / Fitting Back .157 From Condenser (2")

i 28. Heaters 5 & 6. Drains 20" Elbow .378

29. Heaters S & 6 Drains 16" Elbow .320
30. MSR 1st Stage Excess Stm. 3" Elbow .176
31. MSR ist Stage Excess Stm. 3" Elbow .176
32. MSR 1st Stage Excess Stm. 3" 45* Elbow .176
33. MSR 1st Stage Excess Stm. 2" Pipe .172
34. HSR 1st Stage Excess Stm. 2" Pipe .172
35. MSR 1st Stage Excess St:n. 3" 45' Elbow .176
36. MSR 1st Stage Excess Stm. 3" Elbou .176

, 37. MSRilst Stage Excess Stm. 3" Elbow .176

- y 38. MSIList Stage Excess Stm. 3" Elbow .176 Unit 16th Rrif0elin,g Outage

1. Extr. Stm. to LP Heater 5 16" 90* Elbow .379
2. Extr. Stm. to LP Heater 5 16" 90* Elbow .379
3. Extr. Stm. to LP Heater 5 16" 90 Elbow .379 si Extr. Stm. to LP Heater 5 16" 90 Elbow .379
5. Extr. Stn, to LP Heater 5 24" 90* Elbow .513
6. Extr. Stm. to LP Heater 5 20" 45* Elbow .449
7. MSR Shell Drains 10" Pipe Bend .283
8. MSR Shell Drains 14" 45" Elbow .285
9. Heaters 5 & 6 Drains 10" Pipe Bend (Upper) .312
10. Heaters 5 & 6 Drains 12" Pipe (Tank Conn.) .314

,11. Featers 5 & 6 Drains 16" 90 El bow .289

12. 'deater Drain Tank Drains 20" 90' Elbow .299

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13. Hea.er Drain Tank Drains 20" 90* Elbow .299
14. Water Drain Tank Drains 20" Pipe 2' Downstream .299

- of Valve N1N26V530B

~)h, heater Prain Pump Discharge 12" 90 Elbow (Vertical) .362 1E. thater Drtin Pump Discharge 12" 90 Elbow .362 17.c HSR 1stt5tage Drains -6" Pipe Bend .248 18.' MSR 1st Stage Drains 6" Pipe Bend .248

19. 'MSR lst Stage Drains 12" 90 Elbow .282 2') . MSR 2nd Stage Dra.f r.s 14" Pipe 2' Downstream .285 t of Valve N1N26V536A

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4 TABLE 1 INSPECTION ITEM DESCRIPTION

' Unit 1 6th Refueling Outage Mi nimum Program Acceptable Item System Description Thickness

21. MSR 2nd Stage Drains 8" Pipe Bend (Upper) .372
22. MSR 2nd Stage Drains 12" 90 Elbow (Lower Vert) .339
23. Heater Drain Tank Vents 8" Elbow .250
24. Heater Drain Tank Vents 8" Tee .250 a
25. Heater Drain Tank Vents 8" Pipe Bend .250  !
26. Heater Drain Tank Vents 8" Tee .250
27. MSR 2nd Stage Excess Stm. 3" 45 Elbow (2) .247
28. MSR 2nd Stage Excess Stm. 3" 90 Elbow .247
29. Extr. Stm. to MSR ist Stage 8" 45 Elbow .273
30. Extr. Stm. to MSR ist Stage 8" Pipe Bend .273
31. Extr. Stm. to MSR 1st Stage 8" Pipe Bend .273
32. Extr. Stm. to MSR ist Stage 8" 90" Elbow (Horizontal) .273
33. Extr. Stm. HP Heater 6 - 12" Pipe Bend .349
34. Extr. Stm. HP Heater 6 12" Pipe Bend .349
35. Extr. Stm. HP Heaters 6A&6B 16" 90* Elbow .426
36. Extr. Stm. HP Heaters 6A&6B 12" 90" Elbow .349
37. Extr. Stm. HP Heaters 6A&6B 16" 90' Elbow .426
38. Extr. Stm. to MSR ist Stage 14" Elbow .376
39. Extr. Stm. to MSR 1st Stage 14" Pipe Bend .376
40. . Extr. Stm. to MSR ist Stage 8" Pipe Bend .273
41. Extr. Stm. to MSR 1st Stage 8" 45" Elbows (2) .273
42. Extr. Stm. to MSR 1st Stage 8" 45 Elbows (2) .273
43. Extr. Stm. to MSR 1st Stage 14" Pipe Bend .376
44. Extr. Stm. to MSR 1st Stage 14"x8" Reducer, Tee & Elbow .376/.273
45. Extr. Stm. to MSR ist Stage 6" Elbow .236
46. Extr. Stm. to MSR 1st Stage 8" Pipe Bend .273
47. Extr. Stm. to MSR 1st Stage 8" 45" Elbows (2) .273
48. Extr. Stm. to MSR 1st Stage 8" Elbow .273
49. Extr. Stm. to MSR 1st Stage 8" 45' Elbow & Pipe Bend .273
50. Extr. Stm. to MSR 1st Stage 8" Pipe Bend .273
51. Extr. Stm. to MSR 1st Stage 6" Pipe Bend .236 l
52. Extr. Stm. to MSR 1st Stage 8" Pipe Bend .273 I
53. Extr. Stm. to Heaters 6A&6B 12" Elbow .349
54. Extr. Stm. to Heaters 6A&6B 12" 45* Elbow .349 ,
55. Extr. Stm. to Heaters 6A&6B 12" 45* Elbow .349 I
56. Extr. Stm. to Heaters 6A&6B 12" Pipe Bend .349 i
57. Extr. Stm. to Heaters 6A&68 12" 45 El bow .349
58. Extr. Stm. to Heaters 6A&6B 12" 45" Elbow .349
59. Extr. Stm. to Heaters 6A&6B 12" Pipe Bend .349 1

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TABLE I.

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' INSPECTION' ITEM DESCRIPTION'

- Unit 1- 6th Refueling Outage Mi nimum

' Program . ..

Acceptable'

' Item -System Description Thickness

60. Extr. ' Stm. to Heaters 6A86B 16"x12" Reducer, Tee & Elbow 426/.349
61. Extr. Stm. to Heater 5 1<6" Elbow- .379

'62. Extr. Stm. to Heater 5 - 24" Elbow: , .518

63. Extr.-Stm. to Heater 5- 20" Elbow .449-
64. . Extr. Stm. to Heater 5 20" Elbow .449-
65. Extr. Stm. to Heater 5 20" Elbow .

.449-66.- - Extr. Stm. to Heater 5 20" Piping l'. Either Side of .449 Vent Connection

1. Cold Reheat ' Crossunder 37.5" Turning Yane .604-Piping.
2. Cold Reheat - Crossunder 37.5" Expansion Joint .604 Piping
3. - Cold Reheat - Crossunder 37.5" 4k' Turning Vane .604 Piping 4 Cold Reheat - Crossunder 37.5" Expansion Joint .604 Piping
5. - Cold Reheat - Crossunder 37.5" Turning Vane .604 Piping Unit 1 7th Refueling Outage
1. Extr. Stm. to LP Heater 5 16" 90* Elbow 45" Elbow Nozzle .279
12. Extr. Stm to LP Heater 5 16" 90 Elbow .279
3. Extr. Stm. to LP Heater 5 16" 90* Elbow .279
4. Extr. Stm. to LP Heater 5 24" 90* Elbow

.395

5. Extr. Stm.' to LP Heater 5 24" x 20" Tee .395/.337
6. Extr. Stm. to LP Heater 5 20" 45' Elbow .337
7. Extr. Stm. to LP Heater 5 20" 90* Elbow .337
8. Heater 1 Drains 24" 90* Elbow .222
9. Extr. Stm. to Heater 2A 22" Short Radius Elbow .216

- 10. MSR 2nd Stage Excess Stm. 3" x 2-1/2" Reducer .182/.170 11.- MSR 2nd Stage Excess Stm. 3" x 2-1/2" Reducer .182/.170

12. MSR 2nd Stage Excess Stm. 3" x 2-1/2" Reducer .182/.170
13. MSR 2nd Stage Excess Stm. 3" x 2-1/2" Reducer .182/.170
14. Htr. 5-Drains 8" 90* Elbow .189
15. Htr. Drain Tank Drains Vents 8" 90 Elbow .189
16. Cond. Discharge to Cond. "B" 10" 90* Pipe Bend .262
17. Feedwater Min. Flow & Wet -6" Straight Pipe .359 Layup

________-_-______ - - _ ~

L \ L L

' ~

' TABLE I a- ,

' INSPECTION ITEM DESCRIPTION s

~ Unit 1"7th Refueling Outage

.g '

L' Minimum

Program _

. Acceptable

Item System Description Thickness i
18. Feedwater Min. Flow & Wet 6" .Strai ght' Pipe - .359 Layup
19.- MSR 1st Stage Drains, 6" x 6" Tee .194
20. MSR lst Stage Drains. 6" 90' Elbow'- .194-

-21. MSR-2nd Stage Drains 6" 90* Elbow

. .290 22.- ' MSR 2nd Stage Drains 8" 90" Pipe Bend .315'

23. MSR 2nd Stage Drains  ; 8" 90* Elbow .315.

24.' Htr Drain Pump Min.- Flow - 8" 90 Elbow & 8"x 4" Reducer .189/.155 Unit 1 Feed Pump Suction Piping a-1.- Feed Pump Suction-- 18" Pipe Bend .420 r

2. . Feed Pump Suction 24" x 18" . Wel dol et .536 3; Feed Pump. Suction

. 24.90 Elbow' . 536 i

Unit 2 2nd Refueling Outage 1.- Extr. Stm. to LP Heater 5' 16" Elbow .342'

2. Extr. Stm. to LP. Heater 5 24" x 16"' Reducing Tee'

.467/.342

3. Extr. Stm. to LP Heater 5 20" Elbow .404
4. Extr. Stm. to MSR 14" Elbow .389
5. .Extr. Stm. to MSR- 14" x 8" Reducer & Y Branch .344/.249 6.. Extr. Stm. to'MSR 8" 45 Elbow .249
7. - Extr.-Stm. to MSR 8" Pipe Bend .249 8.- Extr.'Stm. to MSR ' 8" Pipe Bend .249
9. 'Extr. Stm. to HP Htr.(6A&6B) 12" Elbow .319
10. Extr. Stm. to HP Htr.(6A&6B) 16" x 12 Reducer, Tee .389/.319

& Elbow

11. Extr. Stm to HP Htr.(6A&6B) 12" . Pipe Bend .319
12. MSR Shell Drains 14" 45* Elbow .258
13. MSR Shell Drains 12" Elbow .252
14. MSR 2nd. Stage Drains 12" Elbow .295
15. MSR 2nd Stage Drains 12" Tee .295
16. MSR 2nd Stage Drains 12" Elbow .295 17, 2nd Stage.MSR Startup and 3" Elbow .225 Excess Stm. Vents
18. 2nd Stage MSR Startup and 3" 45' Elbow .225 Excess Stm. Vents
19. 2nd Stage MSR Startup and 3" Elbow .225 Excess Stm. Vents

i

. 1 TABLE I i

INSPECTION ITEM DESCRIPTION Unit 2 2nd Refueling Outage Minimum Program Acceptable Description l

Item System Thickness

! 20. MSR Cross Under Piping 37-1/2" Elbow .562 l 21. Main Steam Drains 2" x 1" Reducing Tee .169/.136

22. Main Steam Drains 2" Elbow-l' Downstream of V555A .174
23. Main Steam Drains 2" Tee .174
24. Main Steam Drains 2" Elbow-l' Downstream of .174 Control Valve j
25. Extr. Stm. Drains for 2" Elbow-l' Downstream of V590 .155 Heaters 4, 5, 6
26. Extr. Stm. Drains for 2" Pipe-l' Downstream of .155 Heaters 4, 5, 6 Orifice
27. Extr. Stm. Drains for 2" Elbow-l' Downstream of V576 .122 Heaters 4, 5, 6 j
28. Extr. Stm. Drains for 2" Elbow-5' Downstream of V574 .122 i Heaters 4, 5, 6
29. Htrs 5&6 Drains to Htr 20" Elbow .245 i Drain Tank & Pump
30. Htrs 5&6 Drains to Htr 16" Elbow .263 Drain Tank & Pump
31. Htrs S&6 Drains to Htr 12" Reducer .253 Drain Tank & Pump
32. Extr. Stm. Drains for 2" 45* Elbow .122 Htr>. 6A & 6B
33. Extr. Stm. Drains for 2" Elbow .122 Htrs. 6A & 6B
34. Extr. Stm. Drains for 2" Elbow .122 Htrs. 6A & 6B
35. Extr. Stm. Drains for 2" Elbow .122 i Htrs. 6A & 6B
36. Extr. Stm. Drains for 2" 45 Elbow .122 Htrs. 5A & 6B  ;
37. Extr. Stm. Drains for 2" 45 Elbow .122 l Htrs. 6A & 6B
38. Extr. Stm. Drains for 2" 45 Elbow .122 Htrs. 6A & 6B  :

I Unit 2 3rd Refueling Outage

1. Extr. Stm. to LP Htr. 5 16" Elbow .342  !
2. Extr. Stm. to LP Htr. 5 16" Elbow .342 1 1

I l

l

TABLE I INSPECTION ITEM DESCRIPTION i

( Unit 2 3rd Refueling Outage Minimum Program Acceptable Item System Description Thickness

3. Extr. Stm' to LP Htr. 5 16" Elbow .342
4. Extr. Stm. to LP Htr. 5 24" Elbow .467
5. Extr. Stm. to MSR 14" x 8" Reducer & Y Branch .344/.249
6. Extr.-Stm. to MSR 8" Pipe Bend .249
7. Extr. Stm. to MSR 14" Elbow .344
8. Extr. Stm. to MSR 8" 45* Elbow .249
9. Extr. Stm. to MSR 8" Pipe Bend .249
10. Extr. Stm. to HP Htrs 6A&6B 12" Pipe Bend .319
11. Extr. Stm. to HP Htrs 6A&6B 16" Elbow .389
12. Extr. Stm. to HP Htrs 6A&6B 16" Pipe Tee .389
13. Extr. Stm. to HP Htrs 6A&68 12" Elbow .319
14. Extr. Stm. to HP Htrs 6A&6B 16" Elbow .389
15. MSR Shell Drains 14" 45 Elbow .258
16. MSR 2nd Stage Drains 8" Pipe Bend .372
17. MSR 2nd Stage Drains 8" Pipe Tee .372
18. 2nd Stage MSR Startup & 3" 45 Elbow .225 Excess Stm. Vents
19. 2nd Stage MSR Startup & 3" Elbow .225 Excess Stm. Vents
20. 2nd Stage MSR Startup & 3" 45* Elbow .225 Excess Stm. Vents 21, 2nd Stage MSR Startup S. 3" 45 Elbow .225 Excess Stm. Vents
22. 1st Stage MSR Startup & 2" Elbow .172 Excess Stm. Vents
23. 1st Stage MSR & Excess 3" 45 Elbow .178 Stm. Vents
24. 1st Stage MSR & Excess 3" Elbow .178 Stm. Vents
25. 1st Stage MSR & Excess 2" 45 Elbow .172 Stm. Vents
26. Htro. 5 & 6 Drains to Htr. 20" Elbow .246 Drain Tank & Pump
27. Htes. 5 & 6 Drains to Htr. 20" Pipe-2' Downstream of V5308 .246 Drain Tank & Pump
28. 1st Stage HSR & Excess 2" Elbow .172 Stm. Vents
29. 1st Stage MSR & Excess 2" Elbow .172 Stm. Vents t.

TABLE I INSPECTION ITEM DESCRIPTION i

Unit 2 3rd Refueling Outage j

, Mi nimum l Program Acceptable Item System Description Thickness

1. Cold Reheat - Crossunder 37.5" Expansion Joint .604 Piping
2. Cold Reheat - Crossunder 37.5" Turning Vane .604 Piping
3. Cold Reheat - Crossunder 37.5" Expansion Joint .604 Piping
4. Cold Reheat - Crossunder 37.5" Turning Vane .604 l Piping ,
5. Cold Reheat - Crossunder 37.5" Expansion Joint .604 l Piping
6. Cold Reheat - Crossunder 37.5" Pipe .604 Piping
7. Cold Reheat - Crossunder 37.5" Pipe .604 Piping
8. Cold Reheat - Crossunder 37.5" Turning Vane .604 Piping Unit 2 4th Refueling Outage
1. Extr. Stm. to #5 Heaters 16" Conn. to X-under, 90' .279

& 45 ELL

2. Extr. Stm to #5 Heaters 16" Conn. to X-under, 90* .279

& 45' ELL

3. Extr. Stm. to #5 Heaters 24" x 16" Tee .395
4. Extr. Stm. to #5 Heaters 24" x 20" Tee .395/.337
6. Extr. Stm. To #5 Heaters 20" 90' ELL .337
7. Extr. Stm. to #6 Heaters 16" x 16" Tee .350
8. Extr. Stm. to #6 Heaters 16" 90 ELL .350
9. Extr. Stm. to #6 Heaters 16" x 12" Tee .319
10. Extr. Stm. to MSRs 8" 45* ELL .210
11. Extr. Stm. to MSRs 8" 90* ELL .210
12. Extr. Stm. to #2 Heaters 30" 90' ELL .309
14. Extr. Stm. to #2 Heaters 22" 90 S.R. ELL .229
15. 1st Stage Excess Steam Two 2" 90 ELLS .111
16. 1st Stage Excess Steam Two 3" 90' ELLS .146
17. 1st Stage Excess Steam Two 3" 90" ELLS 8 3" x 2-1/2" .146 Reducer
18. 1st Stage Excess Steam 2-1/2" x 2" Reducer & 2" .147 ELL Downstream of Orifice
19. MSR 1st Stage Drains 6" x 6" Tee .263

TABLE I INSPECTION ITEM DESCRIPTION

. Unit 2 '4th Refueling Outage Minimum Program Acceptable.

Item System Description Thickness

20. MSR ist Stage Drains 6" ELL .194 21 '. Extr. Stm. to #1 Heaters 26" S.R. ELL .244
22. Cold Reheat (Crossunder) 37-1/2" ELL (Downstream only)

. .491

23. Cold Reheat (Crossunder): 37-1/2" ELL (Downstream only) .606
24. MSR 2nd Stage Drains 6" 90 ELL .365
25. 2nd Stage Excess Steam 3" x 2-1/2" Reducer .162 Downstream of Orifice
26. 2nd Stage Excess Steam (2) 3" 90" ELLS .278
27. 2nd Stage Excess Steam 2" x 2" Tee .154
28. _ . Auxiliary Steam 6" x 6" Tee .172
29. Heater #1 Drains 24" 90" ELL .286-
30. Htr Drain Pump Min. Flow 8" 90" ELL .222
31. Cond. Pump Minimum Flow 10" 90 Pipe Bend .262 l 32.. Cond. Pump Minimum Flow 14" Condenser Connection .210
33. Feedpump Minimum Flow 6" Pipe Spool Piece .172-
34. Feedpump Minimum Flow 6" Pipe Spool Piece .172 _,
35. Cold Reheat (Crossunder) 37-1/2" ELL (Downstream) .491 Piping
36. 2nd Stage Excess Steam 3"'x 2-1/2" Reducer- .182
37. 2nd Stage Excess Steam 3" x 2-1/2" Reducer .182
38. 2nd Stage Excess Steam 3" x 2-1/2" Reducer- _

.182

39. 2nd Stage Excess Steam 3" Pipe Spool Piece Past V523B .182 J. Extr. Stm. to MSRs. 8" Pipe Bend .21 K. 'Extr. Stm. to MSRs. 8" Elbow .21 L. Extr. Stm. to MSRs. 8" Pipe Bend .21 Unit 2 Feed Pump Suction Piping
1. Feed Pump Suction 18" 90" Elbow .420
2. Feed Pump Suction 24" Tee & Two 24" x 18" Red. .536/.420 1
3. Feed Pump Suction 24" x 18" Tee and Reducer .536/.420 i
4. Feed Pump Suction 18" Pipe Bend .420
5. Feed Pump Suction 24" 90 Elbow .536
6. Feed Pump Suction 18" x 12" Tee .420
7. Feed Pump Suction 18" x 12" Tee .420 l
8. Feed Pump Suction 18" 90" Elbow .420
9. Feed Pump Suction 24" 90* Elbow .536
10. Feed Pump Suction 18" Pipe Bend .420

_ _ _ _ _ _ _ _ _ - - - - . _ _ _ _ _ _ _ - - _ - - - - - _ - - - - - - - - . - _ - - _ - - - _ _ - - _ _ - - - _ _ _ _ _ _ - . - - - - - - - - - d

TABLE II THICKNESS MEASUREMENT RESULTS FOR FITTINGS IDENTIFIED AS UNACCEPTABLE Unit 16th Refueling Outage - April,1985 Minimum Program Acceptable Actual Item System Description Thickness Thickness

1. Extr. Stm. to LP Htr. 5 16" 90* Elbow- .379 .105
2. Extr. Stm. to LP Htr. 5 16" 20' Elbow .379 .217
4. Extr. Stm. to LP Htr. 5 16" 90* Elbow .379 .250
29. Extr. Stm. to MSR 1st Stage 8" 45* Elbow .273 .165
30. Extr. Stm. to MSR 1st Stage 8" Pipe Bend .273 .208
33. Extr. Stm. to HP Htr. 6 12" Pipe Bend .349 .266
34. Extr. Stm. to HP Htr. 6 12" Pipe Bend .349 .279
39. Extr. Stm. to MSR ist Stage 14" Pipe Bend .376 .305
43. Extr. Stm. to MSR 1st Stage 14" Pipe Bend .376 .286
44. Extr. Stm. to MSR 1st Stage 14" x 8" Reducer, .376/ .316/

Tee & Elbow .273 .206

45. Extr. Stm. to MSR 1st Stage 6" Elbow .236 .141
53. Extr. Stm. to Htrs. 6A & 6B 12" Elbow .349 .256
56. Extr. Stm. to Htrs. 6A & 6B 12" Pipe Bend .349 .278
59. Extr. Stm. to Htrs 6A & 6B 12" Pipe Bend .349 .254 Unit 17th Refueling Outage - October 1986
10. MSR 2nd Stage Excess Stm. 2" x 2-1/2" Reducer .182 .149
11. MSR 2nd Stage Excess Stm. 3" x 2-1/2" Reducer .182 .147
12. MSR 2nd Stage Excess Stm. 3" x 2-1/2" Reducer .182 .148
13. MSR 2nd Stage Excess Stm. 3" x 2-1/2" Reducer .182 .116 Unit 2 2nd Refueling Outage - September 1983 ,
27. Extr. Stm. Drains for 2" Elbow, l' .122 .119 Heaters 4, 5, 6 Downstream of V576 1
34. Extr. Stm. Drains for 2" El bow, 5 ' .122 .122 Heaters 4, 5, 6 Downstream of V576
35. Extr. Stm. Drains for 2" Elbow .122 .100 Heaters 6A & 6B
36. Extr. Stm. Drains for 2" 45* Elbow .122 .100 Heaters 6A & 68
37. Extr. Stm. Drains for 2" 45 Elbow .122 .103 Heaters 6A & 6B
38. Extr. Stm. Drains for 2" 45 Elbow .122 .072 Heaters 6A & 6B TABLE Il THICKNESS MEASUREMENT RESULTS FOR FITTINGS IDENTIFIED AS UNACCEPTABLE Unit 2 3rd Refueling Outage - January 1985 Minimum Program Acceptable Actual Item System Description Thickness Thickness
11. Extr. Stm. to HP Htrs 6A&6B 16" Elbow .389 .345 22, 1st Stage MSR Startup & 2" Elbow .172 .125 i Excess Steam Vents 1
25. 1st Stage MSR & Excess 2" 45' Elbow .172 .142 l Steam Vents
29. 1st Stage MSR Excess 2" Elbow .172 .129 i Steam Vents Unit 2 4th Refueling Outage - April 1986
10. Extraction Steam to MSRs 8" 45 Elbow .210 .130
25. 2nd Stage Excess Steam 3" x 2-1/2" Reducer .162 .123
35. Cold Reheat (Crossunder) 37-1/2" Elbow .491 .305 Piping
36. 2nd Stage Excess Steam 3" x 2-1/2" Reducer .182 .131
37. 2nd Stage Excess Steam 3" x 2-1/2" Reducer .182 .128
38. 2nd Stage Excess Steam 3" x 2-1/2" Reducer .182 .144

-r l

(

C TABLE III REPAIR / REPLACEMENT ACTIONS FOR NONCONFORMING WALL THICKNESSES Unit Refueling Outage Date Repair /Repl acement 1 6 04/85 Items 1, 2, and 4 were replaced with carbon steel. Program items 29, 30, 33, 34, 39, 43, 44, 45, 53, 56, and 59 were replaced with stainless steel. .

1 7 10/86 All unacceptable items were replaced with carbon steel. , 4 ,

2 2 09/83 All unacceptable items were replaced wi.th stainless steel.

2 3 01/85 All unacceptable items were replaced with carbon steel. b 2 4 04/86 Items 10, 25, 36, 37, and 38 were replaced with carbon steel. Item 35 was repaired with stainless steel.

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