pipe inspection program report2las2.1a pipe inspection program report 1987 kewaunee nuclear power...

PIPE INSPECTION PROGRAM REPORT 1987

KEWAUNEE NUCLEAR POWER PLANT

JUNE 1987

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PIPE INSPECTION PROGRAM REPORT 1987

KEWAUNEE NUCLEAR POWER PLANT

June 5, 1987

Prepared By:

Reviewed By:

Approved By:

f 6 J1 L CLorf A. Sutton Nuclear Licensin Technician

David W. Sauer Nuclear Licensing Supervisor

Date

6 '7 Date

Date& Systems

2LAS2.1

Dan J. Ropson/ Superintendent-Nuclear Licensing

. 2dt O_

2LAS2.1A

PIPE INSPECTION PROGRAM REPORT 1987 KEWAUNEE NUCLEAR POWER PLANT

EXECUTIVE SUMMARY:

The purpose of the Pipe Inspection Program at the Kewaunee Nuclear Power Plant is to inspect carbon steel piping susceptible to erosion/corrosion in order to repair or replace worn piping before failure to avoid personnel injury, damage to plant equipment, and costly unplanned outages.

Inspection is performed by manual ultrasonic (UT) examination. This inspection method includes the removal of asbestos and nonasbestos insulation, surface preparation (grid marking and buffing to remove surface scale and paint), manual UT examination, repair or replacement of piping when necessary, and insulation replacement with nonasbestos insulation.

The Pipe Inspection Program Report 1987 summarizes the inspection work performed from the first year of the program (1983) through the 1987 refueling outage. The report describes the inspection program, the results of the program, and inspection plans for future outages.

CONCLUSION

Kewaunee has had an aggressive pipe inspection program in place since its 1983 refueling outage. Inspections have been performed in all secondary steam systems and in selected systems with single phase flow conditions. Piping replacements have been made in five of the eight systems inspected. A schedule for inspection of additional systems and reinspection of systems will be formulated during the 1987 calendar year.

TABLE OF CONTENTS

1.0 Introduction

2.0 Summary of Program Scope by year

3.0 Inspection Plans for the 1988 Refueling Outage

4.0 Lines Inspected by Year

5.0 Lines Replaced by Year

6.0 Deleted

7.0 Results of Analysis

8.0 Conclusions

Attachment 1 - 900 Elbow Inspection Grid

Attachment 2 - Supplemental Graphics

2LAS2.3

1.0 Introduction

1.1 Purpose

The purpose of the pipe inspection program at the Kewaunee Nuclear

Power Plant (KNPP) is to:

a. inspect piping susceptible to wall thinning by erosion/corrosion,

b. document the results of the inspection,

c. manage the data and documentation such that meaningful conclusions

can be drawn with respect to the rate of thinning,

d. replace piping as necessary due to wall thinning, and

e. recommend to management a course of action for the future.

1.2 Selection Criteria

KNPP has had a pipe inspection program in place since its 1983

refueling outage (cycle 8-9). The program encompasses systems with

single phase and two phase flow conditions; however, the majority of

the inspections that have been performed were performed on systems

with two phase flow. The inspection of two phase flow systems has

been emphasized since severe erosion/corrosion has been detected in

some of these systems. Components (elbow, tee, reducer, spool piece,

etc.) are selected for inspection according to piping configuration.

Generally, all components on a line are inspected. Spool piece

lengths are measured as three pipe diameters, and begin immediately

downstream of a component other than a spool piece. If a number of

components on the line show no significant evidence of wall thinning,

then the number of components inspected on that line may be reduced.

2LAS2.4

The number of inspection points on each component ranges from 8 to 500.

This number is dependent upon the size of the component and the size

of the grid applied to the component. An example of a grid applied to

an elbow is included as Attachment 1 to this report. Systems to be

inspected are selected based on suspected moisture content, piping

material,.and previous plant experience.

1.3 Inspection Methods

The inspection method used at KNPP is manual ultrasonic (UT) examina

tion. Hand-held 0-meters and ultrasonics with an oscilloscope are

predominately used. Radiographs are taken when necessary.

This inspection method includes the removal of asbestos and nonasbestos

insulation, surface preparation (grid marking and buffing to remove

surface scale and paint), manual UT inspection, repair or replacement

of piping when necessary, and insulation replacement with nonasbestos

insulation. Grids are marked directly on the component with grease

pencils. The orientation of the "A" line and "1" line (see Attachment 1)

is indicated on the inspection datasheet to permit relocation of any

given inspection point.

1.4 Repair or Replacement Criteria

The repair or replacement criteria used by KNPP is to compare the

percent of wall degradation for each component to the percent of wall

degradation allowed by ANSI 831.1 for that component. Those com

ponents with wall thicknesses below or near the 831.1 code allowable

wall thickness are repaired or replaced. The results of each line

inspected are examined on an individual basis and corrective actions

are made as appropriate for that line. When the majority of the com-

2LAS2.5

ponents on a given line are below or near the code allowable wall

thickness, it may be cost effective to replace the entire line versus

individual components. (It should be noted that inspection results

are based on the assumptions that all components have original wall

thicknesses equal to their schedule wall thickness. Since component

mill tolerances of ± 121% exist, the actual wall degradation may vary

considerably.)

Stainless steel (ASTM A312 Type 304 or Type 304L) has been selected as

replacement material in most areas where replacement has been

necessary. Stainless steel was selected due to its resistance to

water impingement erosion and resistance to general corrosion;

although, stress corrosion cracking has been exhibited in this

material in high pressure systems at other plants.

1.5 Procedure

General Maintenance Procedure GMP 216, "Pipe Inspection Procedure",

was developed to govern the pipe inspection program. Inspection

results are recorded on the procedure datasheets then entered into the

pipe inspection computer database for trending results. The

datasheets are filed with their respective work.request in the QA

vault for historical reference.

2LAS2.6

1.6 Summary

Kewaunee has had an agressive pipe inspection program in place since

its 1983 refueling outage (cycle 8-9). At the completion of the 1987

refueling outage, more than 2000 components have been inspected. The

following systems have been inspected:

a.

b.

C.

d.

e.

f.

g.

h.

Bleed.Steam and Heater Vents

Condensate

Feedwater and Feedwater Recirculation

Heater and Moisture Separator Drains

Heating Steam

Main Steam, Auxiliary Steam and Steam Dump

-Steam Generator Blowdown Treatment

Turbine Room Traps and Drains

(A detailed list of lines inspected is included in Section 4.0 of this

Report.)

As

in

Single Phase

a. Condensat

a result of the pipe inspection program, piping has been replaced

the following systems:

Approximate No. of Approximate No. Flow Components Replaced Two Phase Flow Components Repla

e 1* a. Bleed Steam and 319

b. Feedwater Recirc 5

Heater Vents

b. Heater and Moistu Separator Drains

c. Turbine Room Trap and Drains

ire 25

is 72

* Defective Component (see paragraph 2.5)

of ced

2LAS2.7

Additional inspections will be performed during future outages on

carbon steel piping in both single phase and two phase flow systems

in areas which have not yet been inspected. Reinspection will be

performed on areas previously inspected which have not been replaced

to continue monitoring for erosion/corrosion.

2LAS2.8

2.0 Summary of Program Scope by Year

2.1 1983 Refueling Outage

The pipe thinning project started during the 1983 refueling outage

after two ruptured elbows in the heater and moisture separator drains

system caused one reactor trip and one reduction to 50% power during

the 1982-83 cycle. An ambitious and accelerated program began during

the 1983 outage which resulted in inspection of 484 components.

Thirty (30) components were replaced during the 1983 refueling outage.

(A summary of lines inspected can be found in Section 4 of this

report. The summary of replacements can be found in Section 5.)

The 1983 inspection and replacement effort was successful since there

were no outages during the 1983-84 cycle due to pipe thinning problems.


Based on the success of the 1983 effort, a reduced program of inspec

tion was initiated during the 1984 refueling outage. A total of 53

piping components were inspected. Five replacements were made that

outage.


Renewed emphasis was placed on'the program during the 1985 outage due

to the age of the plant and industry experience. In addition to the

tasks of removing insulation, inspecting and replacing pipe, an addi

tional task.of developing a pipe inspection data base was initiated.

2LAS2.9

The purpose of the data base is to track wall thinning in individual

components in an effort.to be predictive in our inspections and replace

ments. Several methods have been developed for data reduction including

several printed reports and graphical output (attached).

The number of readings taken during the 1985 outage rose from 53 in 1984

to 159. This represents a 3 fold increase over the previous year but

is still 67% short of the 1983 milestone. The reason the 1983 effort

was not matched was due to the etensive amount of pipe replacement.

The major piping replacement involved the removal of the 24 inch

diameter bleed steam line between the high pressure turbine exhaust

and the 14A, B feedwater heaters. Replacement was made with Type 304

and Type 304L stainless steel.

Another major effort was the replacement of portions of the Moisture

Separator Reheater (MSR) drains to the Heater Drain Tank.


A rupture of a 2 inch diameter excess steam vent from the MSR's to the

15A, B feedwater heaters caused Kewaunee to shut down during the

1985-86 cycle. A manual unit trip was necessary to allow isolation of

the line since the rupture was close enough to the isolation valve

that isolation was deemed to be an unacceptable personnel hazard. The

MSR excess steam vent lines had been inspected during the 1983 outage;

however, our records indicate that we had missed inspection of the

rupture area by a matter of inches. No evidence of thinning

was found in the area inspected at that time; however, other areas

nearby had been replaced.

2LAS2. 10

Following this incident, the scope of the inspection program was

increased to include all secondary steam piping.

A total of 1,242 components were inspected during the 1986 outage.

Replacements consisted of two 10" x 12" Bleed Steam elbows at the high

pressure feedwater heater inlets, the MSR excess steam vent lines to

the high pressure feedwater heaters, feedwater heater 12A vent line,

portions of feedwater heater 13A, 13B, 14A & B, and 15A & B vent lines

and seven trap lines. The portions of feedwater heaters 13A and 138

vent piping were replaced with carbon steel as time did not allow

total replacement of the vent piping with stainless steel.


Inspections performed during the 1987 refueling outage were minimal

since the majority of the secondary steam lines had pr.eviously been

inspected. Planned inspections consisted of the steam generator

blowdown lines outside of containment, and selected areas of the main

steam and feedwater pump recirculation lines. 149 components were

inspected during this outage.

Due to the feedwater pump suction line failure at Surry on

December 9, 1986, the 1987 outage plans were expanded to include

inspection of the Condensate System between the fourth stage heaters

and the feedwater pumps (feedwater pump suction). A two inch inspec

tion grid was applied to this area resulting in an average of 450

inspection points per component. Thirty-four (34) components were

inspected in this system. A 20" x 16" reducer on the feedwater pump

18 suction line was replaced as inspection revealed its wall thickness

to be 26% below nominal wall. This reducer was sent to Taussig

2LAS2.11

Associates, Inc. for metallurgical examination to identify the cause

of the wall thinning. The metallurgical examination results indicated

that the cause of the reduced wall thickness was due to original manu

facturing of the component, rather than erosion/corrosion. The

inspection results of the remaining components in this system showed

values from 0-15% below nominal wall.

A comparison of.Kewaunee's and Surry Unit 2's feedwater/condensate

system was made. The results are as follows:

Surry Unit 2 KNPP

a. Commercial Operation Date 5/73 6/74 b. Operating Temperature 374 0F 3630F c. Operating Pressure 367 psig 300 psig d. Enthalpy 346 Btu/lb 333 Btu/1b e. pH 8.8 - 9.2 9.2 f. Oxygen Content 4 ppb <1 ppb g. Piping Material A106 Gr. B and A106 Gr. B and

A234 Gr. WPB A234 Gr. WPB h. Piping Schedule 80 (0.500 inch) STD (0.375 inch)

KNPP's piping configuration is essentially the same as Surry's. Since

KNPP's and Surry's feedwater/condensate system have essentially the

same operating and chemistry characteristics, and no erosion/corrosion

problem has been found at KNPP, it is possible that Surry's problem

may be due to their water chemistry problems during their initial

years of operation as stated in IE Information Notice 86-106,

Supplement 1.

In addition to the reducer replacement mentioned above, the main steam

drains to condenser connections 25 and the feedwater heaters 11A, 118,

128, 13A, and 13B vents were replaced. These drain and vent lines had

2LAS2.12

been identified as needing replacement during the 1986 outage, but due

to time constraints and the feedwater heater replacements, scheduled

for the 1987 refueling outage, replacement was delayed to 1987.

Five out of six elbows inspected.on the feedwater recirculation lines

showed evidence of erosion on the outer radius of the elbows; however,

the erosion was not severe enough to require replacement. The readings

on the outer radius of the elbows were approximately 15% less than the.

average wall thickness; however, all readings were within the 122%

mill tolerance. These lines will be scheduled for reinspection to be

performed in approximately two years.

Inspection of the steam generator blowdown lines outside of contain

ment showed virtually no evidence of thinning.

The Main Steam System areas selected for inspection were two 30 inch

elbows from steam generator 1A, located on the mezzanine level of the

turbine building. The readings on the outside radius of these two

elbows were approximately 10% less than the average wall thickness of

the elbows. Therefore, it appears that some thinning is evident. All

readings on the elbows were, however, at least 8% greater than the

nominal wall thickness. These areas will be reinspected in approxima

tely three years to characterize the thinning as erosion/corrosion or

as manufacturing induced.

A schedule for inspection and reinspection of systems will be for-

mulated during the 1987 calendar year.

2LAS2.13

3.0 Inspection Plans for the 1988 Refueling Outage

There are no pipe inspections currently planned for the 1988 refueling

outage. All secondary steam systems have been inspected and replaced where

necessary. In addition, suspect systems with single phase flow conditions

have been inspected.

Pipe inspections are expected to continue in 1989 with inspection of the

systems recommended by the pipe inspection schedule which will be for

mulated this year. Current plans for formulation of this schedule are to

prioritize areas to be reinspected according to the results of the prior

inspections. Portions of systems not yet inspected will be prioritized for

inspection according to the results of other lines in the system. Systems

not yet inspected will be prioritized according to the system charac

teristics (flow velocity, temperature, pressure, etc.). In addition, the

computer-generated list of lines inspected depicting susceptibility to

erosion/corrosion (see paragraphs 7.0 and 8.0) will be used as an aid in

prioritizing future inspections.

2LAS2.13

4.0 Lines Inspected by Year

The following tables delineate which lines at Kewaunee have been inspected by year:

Pipe No. of Diameter Components

YEAR LINE INSPECTED (Inches) Inspected

.1983 Bleed Steam To Heater 14A 16 1 Bleed Steam To Heater 14A&B 16 5 Bleed Steam To Heater 148 16 1 Bleed Steam To Heater 15A 10 1 Bleed Steam To Plant Heating 10 4 Cond 0'Flow From Heater 15A To HDT 8 1 Cond 0'Flow From Heater 158 To HDT 8 2 . Condensate Pump 1A Discharge 16 1 Condensate Pump 18 Discharge 16 1 Cylinder Heating Steam Drain To Cond 1A 4,1 3 Feedwater Pump 1A Discharge 16 3 Feedwater Pump 1A&B Discharge 22 1 Feedwater Pump 18 Discharge 16 2 Heater 13A Vent To Cond 1A 1.5,1 56 Heater 138 Vent To Cond 1A 1.5,1 55 Heater 14A Drain To Heater Drain Tank 12 3 Heater 14A Vent To Cond 1A 1.5,1 20 Heater 14A&B Vent To Cond 1A 14,12 2 Heater 18 Drain To Heater Drain Tank 16,12 6 Heater 148 Vent To Cond 1A 1.5,1 20 Heater 15A Drain To Heater Drain Tank 8,6 7 Heater 15A Vent To Cond 1B 1.5,1 20 Heater 158 Drain To Heater Drain Tank 8,6 5 Heater 15B Vent To Cond 1B 1.5,1 20 Main Steam To Air Ejector 3 3 MSR 1A Drain To Cond 1A 6 11 MSR 1A Drain To Heater Drain Tank 12,8 19 MSR 1A Excess Steam Vent To Heater 15A 2 5 MSR 1A Excess Steam Vent To Heater 15A&B 2 1 MSR 1A Excess Steam Vent To Heater 158 2 6 MSR 1A&B Excess Steam Vent To Heater 15A 4 1 MSR 1A&B Excess Steam Vent To Heater 15B 4 1 MSR 18 Drain To Cond 1A 6 6 MSR 18 Drain To Heater Drain Tank 8 6 MSR 1B Excess Steam Vent To Heater 15A 2 6 MSR 18 Excess Steam Vent To Heater 15A&B 2 1 MSR lB Excess Steam Vent To Heater 158 4,2 10 MSR 2A Drain To Cond 1B 6 7 MSR 2A Drain To Heater Drain Tank 12,8 13 MSR 2A Excess Steam Vent To Heater 15A 4,2 6 MSR 2A Excess Steam Vent To Heater 15A&B 2 1 MSR 2A Excess Steam Vent To Heater 158 2 5 MSR 2A&B Excess Steam Vent To Heater 15A 4 1 MSR 28 Drain To Cond 18 6 9

LINE INSPECTED (Con't)

MSR 28 Drain To Heater Drain TankMSR 28 Excess MSR 2B Excess MSR 2B Excess Reheater Drain

Cond 1A Reheater Drain

Cond 18 Reheater Drain

Cond 18 Reheater Drain Reheater Drain Reheater Drain Reheater Drain. Reheater Drain Reheater Drain Reheater Drain Reheater Drain

Steam Vent To Heater 15A Steam Vent To Heater 15A&B Steam Vent To Heater 158 Tank To Heater 15A &

Tank To Heater 15A &

Tank To Heater 15B &

Tank 1A Tank 1A Tank 1A Tank 1B Tank lB Tank 2A Tank 2B Tank 28

Steam Supply Head Trap 03 Line Trap 04 Line Trap 05 Line Trap 08 Line Trap 09 Line Trap 10 Line Trap 11 line. Trap 12 Line Trap 13 Line Trap 14 Line Trap 15 Line Trap 16 Line Trap 17 Line Trap 18 Line Trap 19 & 20 Line Trap 21 Line Trap 22 & 30 line Trap 23 & 24 Line Trap 25, 26, 27 & Trap 28 & 29 Line Turbine Drain Man Turbine Drain Man

LINE INSPECTED

Bleed Steam To Bleed Steam To Bleed Steam To Bleed Steam To Bleed Steam To Feedwater Pump Feedwater Pump

er To

To Cond 1A to Cond 18 To Heater 15A To Cond 1A To Heater 158 To Heater 15A To Cond 1B To Heater 158 MSR 2A

33 Line

ifold 1A ifold 18

heater 14A Heater 14A&B Heater 148 Heater 15A Heater 15B 1A Recirc 18 Recirc

Pipe Diameter (Inches)

8 2 2 4,2

6 6

6

6 6 6 6 6

10,6 6

10,6 6 1 1.5 1 1.5 1.5 1.5 1.5 1.5 1.5 1 1.5 1 1 1

2,1.5 1.51 1.5 1.5 1.5 1 8 8

YEAR

1983

24 24 24,16 12 12 8,6 6

1 1 2 1 1 6 4

2LAS2.14

No. of Components Inspected

10 7 2 8

1 1

3

6 6 7 5 4 8 6 6 5 1 1 2 1 3 3 1 1 1 1 1 3 3 1 3 2 3 1 2 1 2 4

YEAR

1984

2LAS2.15

LINE INSPECTED (Con't)

Heater Drain Tank To Heater 14A Heater Drain.Tank To Heater 14A&B Heater Drain Tank To Heater 14B Heater 13A Drain To Cond 1A Heater 138 Drain To Cond lB MSR 1A Drain To Heater Drain Tank MSR 2A Drain To Heater Drain Tank Reheater Drain Tank 2A To 15A &

Cond 1B Steam Dump To Cond 1A Steam Dump To Cond 1B Trap 31 Line

Pipe Diameter (Inches).

14 14 14 6 6 8 8 6

8 8 2


2 1 3 3 1 5

S3 1

3 11 4

YEAR

1984

YEAR

1985 Bleed Steam To Heater 14A Bleed Steam To Heater 14A&B Bleed Steam To Heater 148 Bleed Steam To Heater 14B and Plant Htg Bleed Steam To Heater 15A&B Bleed Steam To Heater 158 Bleed Steam To Plant Heating Feedwater Pump 1B Recirc Heater Drain Tank To Condenser 1A

11A 118 13A 13A 13B 13B 15A 15B

Drain Drain Drain Drain Drain Drain Drain Drain

To To To To To To To To

Cond 1A Cond 18 Cond 1A Heater 12A Cond 18 Heater 12B Heater Drain Tank Heater Drain Tank

Main Steam To Air Ejector Main Steam To HP Turbine MSR Relief Header Drain To Condenser 18 MSR 1A Drain To Heater Drain Tank MSR 1B Drain To Cond 1A MSR 18 Drain To Heater Drain Tank MSR 2A Drain To Cond 1B MSR 2A Drain To Heater Drain Tank MSR 28 Drain To Cond 1B MSR 28 Drain To Heater Drain TankReheater Reheater Reheater Reheater Reheater Reheater Reheater Reheater

Drain Drain Drain Drain Drain Drain Drain Drain

Tank Tank Tank Tank Tank Tank Tank Tank

1A 1A 1A 18 1B 2A 28 28

Steam Dump To Cond 1A Steam Dump To Cond 1B

To To To To To To To To

Cond 1A Cond 1B Heater 15A Cond 1A Heater 15B Heater 15A Cond 18 heater 15B

24,16 24,16 24,16 24 16,12 16 10 8

14,8 10,8 10,8 6

8,6 6

8,6 14,8,6 8

3,1.5 30 2

8,6 6

8,6 8,6 12,8 8,6 8 6 6 6 6 6

10,6 6

10,6 8 8

LINE INSPECTED

Heater Heater Heater Heater Heater Heater Heater Heater

2LAS2.16

LINE INSPECTED

Aux Steam From Aux Steam From Aux Steam From Bleed Steam To Bleed Steam To Bleed Steam To Bleed Steam To Bleed Steam To Bleed Steam To

Pipe Diameter (Inches)YEAR

1986

Crossunder Drain To Cond Conn 28 Crossunder Drain To Htr Drain Tank Cylinder Heating Steam Drain To Cond Float Trap Line Freeblow From Main Steam Header 1A Freeblow From Main Steam Header 18 Gland Seal Strainers To Floor Drain Gland Steam Cond To Cond 18 Gland Steam Supply Line Gland Steam Supply Strainer To Waste Heater 11A Drain To Cond 1AHeater Heater Heater Heater Heater Heater Heater Heater Heater Heater Heater Heater Heater

11A 11B 11B 12A 12A 12B 128 13A 13A 13A 138 13B 14A

Vent To Cond 1A Drain To Cond 18 Vent To Cond 18 Drain To Cond 1A Vent To Cond 1A Drain To Cond 18 Vent To Cond 18 Drain To Cond 1A Drain To Heater 12A Vent To Cond 1A Drain To Cond 1B Vent To Cond lB Drain To Heater Drain Tank

1A

Heater 14A&B Drain To Heater Drain Tank Heater 14A & B Vent To Cond 1A Heater 148 Drain To Heater Drain Tank Heater 15A Drain To Heater Drain Tank Heater 15A&B Vent To Cond 18 Heater 158 Drain To Heater Drain Tank Heating Steam Main Steam To Hogging Jet Main Steam To MSR 1A Main Steam To MSR 18 Main Steam To MSR 2A Main Steam To MSR 2B MSR Excess Steam Vent To Heater 15A MSR Excess Steam Vent To heater 158 MSR 1A Excess Steam Vent To Cond 1A MSR 1A Excess Steam Vent To Heater 15A&B MSR 1A Excess Steam Vent To Heater 158 MSR 1A To Reheater Drain Tank 1A

S/G 1A To TDAFWP S/G 1A&B To TDAFWP S/G 1B To TDAFWP Heater 14A Heater 148 Heater 15A Heater 15A&B Heater 15B Plant Heating

3 3 3 16 16 12,10 16 12 10 2,1.5 2,1 1 2 1 1 2 3 2 2 6 2.5 6. 2.5 4 2.5 4 2.5 6 8,6 3,1.5 8,6 3,1.5 12 16 18,12,10,3 16,12 8 3 8

10,6,4,2.5,2 3 6 6 6 6 4,2 4,2 2 2 2 8


80 4 56

1 1 2 5 1 1 25 5 17 1 6 4 2 1 4 8 7 6 9 7 7 7 9 7 18 7 23 11 15 7 2 24 8 4 5 6 21 3 7 8 7 4 2 3 1 10 4 4

2LAS2.17

Pipe Diameter (Inches)LINE INSPECTED (Con't)

MSR MSR MSR MSR MSR MSR MSR MSR MSR

1B 18 1B 18 1B 2A 2A 2A 2A

Excess Steam Vent Excess Steam Vent Excess Steam Vent Excess Steam Vent To Reheater Drain Excess Steam Vent Excess Steam Vent Excess Steam Vent Excess Steam Vent

To Cond 1A To Heater 15A To Heater 15A&B To Heater 15B Tank 18 To Cond 18 To Heater 15A To Heater 15A&B To Heater 15B

MSR 2A To Reheater Drain Tank 2A MSR 28 Excess Steam Vent To Cond 18 MSR 28 Excess Steam Vent To Heater 15A MSR 28 Excess Steam Vent To Heater 15A& MSR 28 Excess Steam Vent To Heater 158 MSR 28 To Reheater Drain Tank 28 Steam Dump To Cond 1A Steam Dump To Cond 18 Trap 01 Line Trap 02 Line Trap 03 Line Trap 04 Line Trap 05 Line Trap 08 Line Trap 09 Line Trap 10 Line Trap 11 Line Trap 12 Line Trap 13 Line Trap 14 Line Trap 15 Line Trap 16 Line Trap 17 Line Trap 18 Line Trap 19 & 20 Line Trap 21 Line Trap 22 & 30 Line Trap 23 & 24 Line Trap 25, 26, 27 & 33 Line Trap 28 & 29 Line Trap 30 Line Trap 32 Line Trap 33 Line Trap 34 Line Turbine First Stage Drn To Cond Conn 26 Turbine Outer Cylinder Drn Cond Conn 27 Turbine Slop Drain Line Turbine Stm Inlet Pipe Drn Cond Conn 25

B

YEAR

1986 2 4,2 2

4,2 8 2 2 2 2 8

2.5,2 4,2 2

4,2 8

16,8 16,12,8 1,0.75 1.5,1 1,0.75 1.5,0.75 1,0.75 1.5,0.75 1.5,1,0.75 1.5,0.75 1.5,0.75 1.5,1,0.75 1.5,0.75 1,0.75 1.5,0.75 1,0.75 1,0.75 1,0.75 2,1.5,0.75 1.5,1 1.5,1,0.75 1.5,1,0.75 1.5,0.75 1,0.75 1.5,1,0.75 2 0.75 1.25,0.75 2 2 1.5 2

No. of Component5 Inspected

1 8 19 9 -5 1 1 10 4 4 13 8 14 5 3 26 37 11 5 22 20 19 21 19 15 17 23 22 21 11 19 24 15 45 37 26 35 32 47 15 2 7 9 7 8 5 26

2LAS2.17A

Pipe Diameter

LINE INSPECTED (Inches)

Feedwater Pump Suction

Feedwater Pump 1A Recirc Feedwater Pump 18 Recirc Main Steam Line Drain Main Steam To HP Turbine Main Steam To MSR 1A & 2A Steam Generator Blowdown

20,16,14, 12,10 6

8,6 6

30,18 8

8,3,2,1.5


34

5 9 1 14 1 85

YEAR

1987

2LAS2.18

5.0 Lines Replaced by Year

The following table delineates which lines or portions of lines have been replaced by year:

YEAR LINE/PORTION OF LINE REPLACED

Bleed Steam To heater 14A&B Heater 13A Vent To Cond 1A Heater 138 Vent To Cond IB MSR 1A Drain To Heater Drain Tank MSR 1A Excess Steam Vent to Htr 15A MSR 1B Drain To Heater Drain Tank MSR lB Excess Steam Vent To Htr 158 MSR 2B Drain To Heater Drain Tank MSR 2B Excess Steam Vent To Htr 15A MSR 28 Excess Steam Vent To Htr 15B Reheater Drain Tank 28 To Heater 158 Trap 08 Line

LINE/PORTION OF LINE REPLACED

1983

YEAR

1984 Heater 14B 1A Recirc 18 Recirc


Bleed Steam To Heater 14A Bleed Steam To Heater 14A&B Bleed Steam To Heater 14B Bleed Steam To Heater 148 and Plant Htg Bleed Steam To Plant Heating Feedwater Pump 1B Recirc Heater 13A Drain To Cond 1A Heater 13A Drain To Heater 12A Heater 13B Drain To Heater 128 MSR 1A Drain To Heater Drain Tank MSR lB Drain To Heater Drain Tank MSR 2A Drain To Heater Drain Tank MSR 28 Drain To Heater Drain Tank Reheater Drain Tank 2A To Heater 15A


Bleed Steam To Heater 15A Bleed Steam To Heater 158 Heater 12A Vent To Cond 1A Heater 13A Vent To Cond 1A Heater 138 Vent To Cond 1B Heater 14A&B Vent To Cond 1A Heater 15A&B Vent To Cond 18 MSR Excess Steam Vent To Htr 15A MSR Excess Steam Vent To Htr 158

Bleed Steam To Feedwater Pump Feedwater Pump

YEAR

1985

YEAR

1986

LINE/PORTION OF LINE REPLACED (con't)YEAR

1986

Trap Trap Trap

19 31 32

MSR 1A MSR 1A MSR 1B MSR 1B MSR 1B MSR 2A MSR 2A MSR 2A MSR 2B MSR 2B MSR 28 Trap, 02 Trap 08 Trap 13 Trap 17

Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam Steam

Vent Vent Vent Vent Vent Vent Vent Vent Vent Vent Vent

To To To To To To To To To To To

Htr Htr Htr Htr Htr Htr Htr Htr Ht r Htr Htr

15A&B 158. 15A 15A&B 158 15A 15A&B 158 15A 15A&B 158


Feedwater Pump Suction Heater 11A Vent To Cond 1A Heater 118 Vent To Cond 18 Heater 12B Vent To Cond lB Heater 13A Vent To Cond 1A Heater 138 Vent To Cond 18 Turbine Stm Inlet Pipe Drn Cond Conn 25

2LAS2.19

Excess Excess Excess Excess Excess Excess Excess Excess Excess Excess Excess Line LIne Line LIne & 20 Line Line

YEAR

1987

Line

2LAS2.21

7.0 Results of Analysis

Analysis was performed on the thickness data gathered from 1983 through

1987 to identify lines which have a greater tendency for erosion. Lines

are categorized as low, moderate or high susceptibility to erosion.

Lines which have a low rating are those which show less than 15% average

reduction in wall thickness and a maximum thinning of 30% or less. The

value of 15% average thinning was chosen because it is close to the 122%

commercial tolerance allowed in manufacture.

A moderate rating is given to those lines which show an average thinning of

greater than 15%, but less than 25% and a maximum thinning of 40%.

A high susceptibility rating is given to those lines with an average

thinning greater than 25% or a maximum thinning greater than 40%.

The lines are further categorized as to the tendency for the thinning to be

concentrated in certain areas (local) or widely distributed over the length

of the line (global).

The selection criterion is the ratio of average to median thinning. If the

ratio is greater than 1.25, then the average thinning more closely

resembles the majority of the data gathered and the thinning iswidely

dispersed on the line, i.e. global. The value of 1.25 is chosen so that a

distinction can be made between the cases where the mean and median are

approximately equal, and no conclusion can be drawn.

Conversely, if the ratio of median to average thinning is greater than

1.25, the average more closely represents the minority of the data, and the

thinning is, therefore, local.

2LAS2.22

The reader should be cautioned that a selection criteria which lends itself

to computer selection is difficult to develop and is influenced by the

homogeneity of the data. That is, this method assumes that the data was

collected at equal intervals over the length of the line. This was not

always the case. (The data is considered reliable when at least ten com

ponents for a given line are in the database.) The results of this analy

sis is presented to give the reader insight into the magnitude of each

category in comparison with the others.

A bar graph showing the analysis results is presented on the following

page.

SUSCEPTIBILITY TO THINNING (BY LINE COUNT)

ULbBAL LO L GL ( AL LOAL GLOBAL LC;AL CLASS

1 - H Iu6H - ] - NTIE EDi)ATI --- d L OW - SUS EPrfBDLITY

DATA RILIABILITY HI E2= LO

R EQUENCY 100

90

30

70

60

40

A0

10

0

\*

2LAS2.23

8.0 Conclusions

Based on the data gathered to date, we can conclude that there is a wide

range of erosion rates. It is, therefore, convenient to categorize the

lines for inspection in the future. The following inspection frequency is

suggested based on the lines' susceptibility to erosion:

Susceptibility

High

Intermediate

Low

Frequency

2-4 Years

3-5 Years

5-10 Years

A list of lines by susceptibility is attached.

SUSCEPTIBILITY OF KEWAUNEE LINES TO THINNING

HIGH = MEAN THINNING GREATER THAN 25% OR MAX THINNING > 40% MEDIUM = MEAN THINNING BETWEEN 15% AND 25% AND MAX THINNING < 40%

LOW = MEAN THINNING BETWEEN LESS THAN 15% AND MAX THINNING ( 30% TENDENCY IS GLOBAL IF THE RATIO OF AVE/MEDIAN THINNING IS > 1125

AND HIGH IF COUNT ) 10

LINE RATE

MSR IA DRAIN TO HEATER DRAIN TANK MSR 2B DRAIN TO HEATER DRAIN TANK MSR iA EXCESS STEAM VENT'TO HTR iSA TRAP 02 LINE BLEED STEAM.TO HEATER 14A&B MSR iB DRAIN TO HEATER DRAIN TANK MSR 2A DRAIN TO HEATER DRAIN TANK BLEED STEAM TO HEATER 14B AND PLANT HTG BLEED STEAM TO HEATER I5A BLEED STEAM TO HEATER 15B HEATER iiA VENT TO COND IA HEATER iiB VENT TO COND iB TURBINE DRAIN MANIFOLD iA MSR 2B EXCESS STEAM VENT TO HTR IB BLEED STEAM TO HEATER 14A BLEED STEAM TO HEATER 14B BLEED STEAM TO HEATER 15A&B HEATER i3 DRAIN TO HEATER 12B COND O'FLOW FROM HEATER i5B TO HDT FREEBLOW FROM MAIN STEAM HEADER 1B GLAND STEAM COND TO COND iB HEATER DRAIN TANK TO HEATER 14A HEATER DRAIN TANK TO HEATER i 41 MAIN STEAM TO MSR iA & 2A MSR EXCESS STEAM VENT TO HTR 15A MSR EXCESS STEAM VENT TO HTR 15B REHEATER DRAIN TANK TO HTR 15A & COND iB BLEED STEAM TO PLANT HEATING FEEDWATER PUMP iB REC IRC HEATER 14A&B VENT TO COND IA HEATER i5A DRAIN TO HEATER DRAIN TANK HEATER i5B DRAIN TO HEATER DRAIN TANK HEATING STEAM MAIN STEAM TO HP TURBINE MSR iA EXCESS STEAM VENT TO HTR 15D MSR iB EXCESS STEAM VENT TO HTR 15A MSR IB EXCESS STEAM VENT TO HTR 15B MSR 2B EXCESS STEAM VENT TO HTR 15A REHEATER DRAIN TANK A TO COND 1B REHEATER DRAIN TANK 2B TO COND iB TRAF 04 L I NE TRAP 05 LINE

TRAP i4 LINE TRAP 17 LINE TRAP 2i LINE TURBINE STM INLET PIPE ORN COND CONN 25 AUX STEAM FROM S/G IA&B TO TDAFWF CROSSUNDER DRAIN TO HTR DRAIN TANK

HIGH HIGH HIGH HIGH HIGH HIGH HIGH HIGH HIGH HIGH HIGH HIGH HIGH MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM MEDIUM LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW

LOW LOW LOW LOW LOW L. OW LOW LOW LOW

TENDENCY

GLOBAL HIGH GLOBAL HIGH GLOBAL LOW GLOBAL LOW LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW GLOBAL HIGH GLOBAL LOW GLOBAL LOW GLOBAL LOW GLOBAL LOW LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW LOCAL LOW GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GLOBAL HIGH GL.:D AL II GH GLOBAL HIGH GLOBAL HIGH GLOBAL LOW GLOBAL LO0W

1


HIGH = MEAN THINNING GREATER THAN 25% OR MAX THINNING > 40% MEDIUM = MEAN THINNING BETWEEN 15% AND 25% AND MAX THINNING < 40%.

LOW = MEAN THINNING BETWEEN LESS THAN 15% AND MAX lHINNINu < 30% TENDENCY IS GLOBAL IF THE RATIO OF AVE/MEDIAN THINNING IS ) i.25

AND HIGH IF COUNT > 10

LINE

HEATER i2B DRAIN TO COND IB HEATER 13A DRAIN TO HEATER 12A MSR 18 DRAIN TO COND iA TRAP 33 LINE AUX STEAM FROM S/G iA TO TDAFWP AUX STEAM FROM SIG iB TO TDAFWP CROSSUNDER DRAIN TO COND CONN 28 CYLINDER HEATING STEAM DRAIN TO COND iA FEEDWATER PUMP SUCTION :EEDWATER PUMP iA RECIRC HEATER iiA DRAIN TO COND iA HEATER iiB DRAIN TO COND iB HEATER 13A DRAIN TO COND IA HEATER 3A VENT TO COND 1A HEATER 13B DRAIN TO COND 1 HEATER B13 VENT TO COND IB HEATER 14A DRAIN TO HEATER DRAIN TANK HEATER 14A VENT TO COND iA HEATER 14B DRAIN TO HEATER DRAIN TANK HEATER 14 VENT TO COND iA HEATER 15A VENT TO COND 1Q HEATER 151 VENT TO COND 1B MSR iA DRAIN TO COND iA MSR IA EXCESS STEAM VENT TO HTR 15A&B MSR iB EXCESS STEAM VENT TO HTR i5A&B MSR 2A DRAIN TO COND 113 MSR 2A EXCESS STEAM VENT TO HTR I5A&B MSR 2B1 DRAIN TO COND i B MSR 2D EXCESS STEAM VENT TO COND iB MSR 2B EXCESS STEAM VENT TO HTR 15A&B REHEATER DRAIN TANK iA TO GOND iA REHEATER DRAIN TANK 1A TO HEATER i A REHEATER DRAIN TANK 2A TO HEATER 15A REHEATER DRAIN TANK 2B TO HEATER 151 STEAM DUMP TO COND IA

.EAM DUMP TO COND 1 SE AM GENLR ATOR BLOWD'OWiN TRAP Oi LIN E TRAP 03 LINE TRAP 08 LINE TRAP 09 LINE TRAP 10 L I NE TRAP ii L.INETRAP i2 1..INE

TRAP i I LINE TRAP 16 LINE TRAP 1Q LINE

RATE

LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW L C) W LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW LOW

LOW LOW LOW LOW LOW

LOW LOW LOW LOW

T EN DEN CY

GLOBAL LOW GLOBAL LOW GLOBAL LOW GLOBAL LOW LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGHLOCAL HIGH. LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HIGH LOCAL HI GH LOCAL HIGH LOCAL. HIGH LOCAL HIGH LO(CAL. HI.,1 LOCAL HIGH LOCAL HIIGH LOCAL HIGH LOCAL HIGH L CAL. H I GH1 LO CAL H IG H LOCAL HIGH LOCAL HIGIH LOCAL HIGH

SUSCEPTIBILITY OF KEWAUNEE LINES TO THINNING 3.

HIGH = MEAN THINNING GREATER THAN 25% OR MAX THINNING > 40% MEDIUM = MEAN THINNING BETWEEN 15% AND 25% AND MAX THINNING < 40%.

LOW = MEAN THINNING BETWEEN LESS THAN 15% AND MAX-THINNING < 30% TENDENCY IS GLOBAL IF THE RATIO OF AVE/MEDIAN THINNING IS > 1.25

AND HIGH IF COUNT iO

LINE RATE TENDENCY

TRAP 19 & 20 LINE LOW LOCAL HIGH TRAP 22 & 30 LINE LOW LOCAL HIGH TRAP 23 & 24 LINE LOW LOCAL HIGH TRAP 25, 26, 27 & 33 LINE LOW LOCAL HIGH TRAP 28 & 29 LINE LOW LOCAL HIGH TRAP 30 LINE LOW LOCAL HIGH COND O'FLOW FROM HEATER I5A TO HDT LOW LOCAL LOW CONDENSATE PUMP. iA DISCHARGE LOW LOCAL LOW CONDENSATE PUMP 1B DISCHARGE LOW LOCAL LOW FEEDWATER PUMP iA DISCHARGE LOW LOCAL LOW FEEDWATER PUMP IA&B DISCHARGE LOW LOCAL LOW FEEDWATER PUMP iB DISCHARGE LOW LOCAL LOW FLOAT TRAP LINE LOW LOCAL LOW FREEBLOW FROM MAIN STEAM HEADER iA LOW LOCAL LOW GLAND SEAL STRAINERS TO FLOOR DRAIN LOW LOCAL LOW GLAND STEAM SUPPLY LINE LOW LOCAL LOW GLAND STEAM SUPPLY STRAINER TO WASTE LOW LOCAL LOW HEATER DRAIN TANK TO CONDENSER IA LOW LOCAL LOW HEATER DRAIN TANK TO HEATER 14A&B LOW LOCAL LOW HEATER iiB STARTUP DRAIN TO COND iB LOW LOCAL LOW HEATER 12A DRAIN TO COND IA LOW LOCAL LOW HEATER 12A VENT TO COND iA LOW LOCAL LOW HEATER 12D VENT TO COND iB LOW LOCAL LOW HEATER 14A VENT LOW LOCAL LOW HEATER 14A&B DRAIN TO HEATER DRAIN TANK LOW LOCAL LOW HEATER 14D VENT LOW LOCAL LOW HEATER I5A VENT LOW LOCAL LOW HEATER 15A&B VENT TO COND iB LOW LOCAL LOW HEATER 15P VENT LOW LOCAL LOW MAIN STEAM LINE DRAIN LOW LOCAL LOW MAIN STEAM TO AIR EJECTOR LOW LOCAL LOW MAIN STEAM TO HOGGING JET LOW LOCAL LOW MAIN STEAM TO MSR iA LOW LOCAL LOW MAIN STEAM TO MSR 1i LOW LOCAL LOW MAIN STEAM TO MSR 2A LOW LOCAL LOW MAIN STEAM TO MSR 2B LOW LOCAL LOW MSR RELIEF HEADER DRAIN TO CONDENSER 1 LOW LOCAL LOW MSR iA EXCESS STEAM VENT TO COND IA LOW LOCAL LOW MSR !A TO REHEATER DRAIN TANK A LOW LOCAL LOW MSR 1A&B EXCESS STEAM VENT TO HTR 15A LOW LOCAL LOW MSR iA&B EXCESS STEAM VENT TO HTR i5B LOW LOCAL LOW MSR iB EXCESS STEAM VENT TO COND iA L OW LOCAL LOW MSR iB TO REHEATER DRAIN TANK iB LOW LOCAL LOW MSR 2A EXCESS STEAM VENT TO COND 18 LOW LOCAL LOW MSR 2A EXCESS STEAM VENT TO HTR i5A LOW LOCAL LOW MSR 2A EXCESS STEAM VENT TO HTR i5B LOW LOCAL LOW MSR 2A TO REHEATER DRAIN TANK 2A LOW LOCAL LOW MSR 2A&B EXCESS STEAM VENT TO HTR 15A LOW LOCAL LOW


HIGH = MEAN THINNING GREATER THAN 25% OR MAX THINNING > 40%

MEDIUM = MEAN THINNING BETWEEN 15% AND 25% AND MAX THINNING ( 40%

LOW = MEAN THINNING BETWEEN LESS THAN 15% AND MAX THINNING < 30%

TENDENCY IS GLOBAL IF THE RATIO OF AVE/MEDIAN THINNING IS > 1.25

AND-HIGH IF COUNT > 10

LINE RATE TENDENCY

MSR 2B TO REHEATER DRAIN TANK 2B LOW LOCAL LOW

REHEATER DRAIN TANK TO HTR I5A & COND iA LOW LOCAL LOW REHEATER DRAIN TANK TO HTR 15B & COND iB LOW LOCAL LOW

REHEATER DRAIN TANK 1B TO COND iA LOW LOCAL LOW

REHEATER DRAIN TANK iB TO HEATER 15D LOW LOCAL LOW

REHEATER DRAIN TANK 2A TO I5A & COND 1B LOW LOCAL LOW STEAM SUPPLY HEADER TO MSR 2A LOW LOCAL LOW

TRAP 31 LINE LOW LOCAL LOW

TRAP 32 LINE LOW LOCAL LOW TRAP 34 LINE LOW LOCAL LOW

TURBINE DRAIN MANIFOLD iB LOW LOCAL LOW

TURBINE FIRST STAGE DRN TO COND CONN 26 LOW LOCAL LOW

TURBINE OUTER CYLINDER DRN COND CONN 27 LOW LOCAL LOW

TURBINE SLOP DRAIN LINE LOW LOCAL LOW

2LAS2.24

ATTACHMENT 1

900 Elbow Inspection Grid

ABCDE F GHI J A

14 13 12 12 12 13 14

This pattern will vary with pipe size and grid size. The maximum dimensions between inspection points shall not be exceeded.

2LAS2.25

Attachment 2

to

Pipe Inspection Program Report 1987

Supplemental Graphics

PIPE INSPECTION PROGRAM 1983-1987 NwBER OF CONPOtEfTS NSPECTED PER YEAR

1500 COMPONENTS

1000

500

O/

0 19 1983 1984 1985 1986 1987

YEAR

PIPE INSPECTION PROGRAM 1983-1987 NO. OF NSPECTIONS PER SYSTEM

BLEED STEAM

COBO.FWP SUCT)

FEEDWATER

FW RECC

FEATER DRANS

HEATER VENTS

HEATNG STEAM

MAN STEAM

STEAM TO TDAFWP

S/G BLOWDOWN

TRAPS & DRANSI I I I I I I

O 100 200 300 400 500 600 700 800 900 1000

COMPONENTS

I I

mmmmmm

:I i: I I: xc

PIPE INSPECTION PROGRAM NO. OF COMPONNTS EPLACE

1983-1987 PE YEAR

1983 1984 1985 1986 1987*

YEAR

* H-EATM vS'4T

250

200

150

100

50

0

PIPE INSPECTION PROGRAM 1983-1987 NO. OF REL.ACB~vETS PER SYSTEM

aIEEF STEAM

CON.(FWP SUCT)

FEEDWATER

FW RECIRC

HEATER DRANS

HEATER VENTS

F-EATNG STEAM

MAN STEAM

STEAM TO TDAFWP

S/G BLOWDOWN

TRAPS & DRANS

0 50 100 150 200

COMPONENTS

250 300 350I I A I I

PIPE INSPECTION PROGRAMNO. OF STAINLESS VS CARBON

1983-1987 REPLACEMENTS

225

200

175

150

125

100

75

50

25

O

CARBON STEEL

STAINLESS STEEL

1983 1984 1985 1986 1987

PROGRAM 1983-1987BLEED STEAM - THINNING BY LINE

BS TO HTR 14A

BS TO HTR 14A&BI

BS TO HTR

O 6S

148

TO 148 & HTGJ

BS TO'HTR 15A

BS TO HTR 15A&B

BS TO HTM 15B

BS TO PLANT HTG

0 10 20 30 40 50 60 70 80 90 100

AVERAGE PERCENT

MEESE=

Emmmilmmm

PIPE INSPECTION

I I l l I f I l l

THINNED

Sam

PIPE INSPECTION PROGRAM 1983-1987 HEATER VENTS - THINNING BY LINE

FUT TO HTR 14A

FiOT TO HTR

11A TO COND

11B TO COND

12A TO COND

12B TO COND

13A TO COND

13B TO COND

14A&B TO CD

MSR EX STM VENT

AVERAGE PERCENT THINNED

PIPE INSPECTIONTRAPS & DRA

PROGRAM 1983-1987 INS - DRAIN LINES

CYL HTG STM

G.AND SEAL STR

GLAND STM COND

GLAt STM S.PP

TD MANFOLD IA

TLFB 1ST STAGE

TLRB OUTER CYL

TLRB STM .ET

XLtDER TO COND

XLNER TO HDT

/

0 10 20 30 40 50. 60 70 80 90 100

AVERAGE PERCENT

I I I f I I I I

THINNED

PIPE INSPECTION TRAPS & DR

DROGRAM 1 INS - TRAP

983-1987 LINES

TRAP I I TRAP 21 TRAP 31 TRAP 41 TRAP 51 TRAP 8i TRAP 91

TRAP 10 TRAP 11 TRAP 12 TRAP 13 TRAP 14 TRAP 15 TRAP 16 TRAP 17 TRAP 18

TRAP 19 & 20 TRAP 21

TRAP 22 & 30 TRAP 23 & 24

TRAP25,26,27,33 TRAP 28 & 29

TRAP 30 TRAP 33

O

7 7/ 2

=K-12

10 20 30 40 50 60 70 80 90 100


A

PPE NSPECTION PROGRAM 1983-1987

HEATER DRAINS

CONo OFLO-+DT

IDT TO COND

11A TO CD

11B TO CD

1A

1A

16

11B STARTIP DRN

12A TO CD IA

12B TO CD 16

13A TO CD 1A

13A TO 12A

136 TO CD 1B

13B TO

14A TO

14A&B TO

148 TO

15A TO

15B TO

12B

-DT

IDT

FDT

I-DT

FOTI I I I I I I

0 10 20 30 40 50 60 70 80 90

AVERAGE PERCENT

100

THINNED

PPE NSPECTION PROGRAM 1983-1987 HEATER DRAINS - CONTINUED

MSR 1A TO CD 1A MSR IA TO FDT MSR 1A TO RDT

MSR 18 TO CD 1A MSR 18 TO F-T MSR 1B TO RDT

MSR 2A TO CD 18 MSR 2A TO FDT

) MSR 2A TO RDT MSR 2B TO CD 1B

MSR 28 TO HDT MSR 2B TO RDT

RDT 1A TO CD 1A RDT 1A TO CD IB

RDT 1A TO 15A RDT 18 TO CD 1A,

RDT 2A TO 15A ROT 2B TO CD 18

RDT 2B TO 15BI I I i i i i i I

0 10 20 30 40 50 60 70 80 90


100

I///AF/AV

PIPE INSPECTION PROGRAM STEAM TO TDAFWP - ThflG

1983-1987 BY LPE

FROM S/G IA

FROM S/G 1B

FROM S/G 1A&1i


PIPE INSPECTION PROGRAMFW RECIRC - THINNING BY

1983-1987LINE

AVERAGE PERCENT

A

FWP 1A

FWP IB

THINNED

MSR 1A DRAIN 8" LINE

0.50

0.40

0.30

020

0.10

0

YEARS IN SERVICE10 MILS/YR AVG EROSION RATE

~' 30 MILS/YR WORST CASE

+ COMPONENT MINIMUM WALL THICKNESS

A AVERAGE MINIMUM WALL THICKNESS

TO HDT

MSR 1 B DRAIN 8" LINE

TO HDT

(INCHES)

1 2 3 4 5 6 7 8 9 10 11 12 13

YEARS IN SERVICE- 15 MILS/YR AVG EROSION RATE

30 MILS/YR WORST CASE



WALL0.50

0.40

0.20

0.10

0

NOMINAL WALL.

AVG EROSION RATE

+ +

+ WORST CASE

B+ ++

831.1 WALL

0

030o

MSR 2A DRAIN TO 8" LINE

(INCHES)

0 1 2 3 4 5 6 7 8 9 10 1112

YEARS IN SERVICE-'10 MILS/YR AVG EROSION RATE

-'20 MILS/YR WORST CASE



WALL

HDT

0.50

0.40

0.30

0201

0.10

0

+

NOMINAL WALL

G EROSION RATE + +

WORST CASE

831.1 WALL

I I I I I I I I I I I I-1 13

MSR 2B DRAIN TO 8" LINE

HDT

(INCHES)

0 1 2 3 6 7 8 9 10 11 12 13

YEARS IN SERVICE

- 10 MILS/YR AVG EROSION RATE

- 20 MILS/YR WORST CASE



WALL0.50

0.40

0.30

020

0.10

0

-+ NOMINAL WALL

VG EROSION RATE

WORST CASEA

+ +

831.1 WALL WALL-- --- --N--- --- -

- - - - - -

BLEED STEAM TO FW HTR 160 LINE

14A & 14B

(INCHES)

1 2 4 0 6 7 8 9 10 11 12 13

YEARS IN SERVICE-10 MILS/YR AVG EROSION RATE

-30 MILS/YR WORST CASE



WALL0.50

0.40 I-

030

020

0.101

NOMINAL WALL +

+ A .AVG EROSION RATE +

N+

WORST CASE A

-A

B31.1 WALL

+

0O

C

BLEED STEAM TO FW HTR 24" LINE

14A &

YEARS IN SERVICE

-10 MILS/YR AVG EROSION RATE

- 20 MILS/YR WORST CASE



14B

0.60

0.50

0.40

030

0.20

0.10

013

4


15A & 15B

(INCHES)

0 1 2 3 4 5

YEARS

6 7 8 9 10 11 12 13

IN SERVICE

~ 5 MILS/YR AVG EROSION RATE

-15 MILS/YR WORST CASE



0.60 WALL

0.50 H

0.40

0.301

0.201

NOMINAL WALL

VG EROSION RATE

WORST C

+

B31.1 WALL

I

0.10

0

- i


15A & 15B

(lNCHFS~

+

- - - 831.1 WALL

1 2 3 4 5 6 7 8 9 10 11 121

YEARS IN SERVICE3 MILS/YR AVG EROSION RATE

-'6 MILS/YR WORST CASE



u.o IWALL

0.50 H

0.40NOMINAL WALL

ROSION RATE +

0.330WORST CASE

020

0.10 -

0'3

(INCHER)

HEATER 14A DRAIN 12" LINE

TO HDT

(INCHES)

AVG EROSION RATE

1 2 3 4 5 6 7 8 9 10 11 12 13

YEARS IN SERVICE-,2 MILS/YR AVG EROSION RATE

WORST CASE



WALL0.60

0.50

0.40

030

0.201

0.10

01 C

NOMINAL WALL +

B31.1 WALL ( INCES

~ 5 MILS/YR

HEATER 14B DRAIN 12" LINE

TO HDT

(INCHES)

AVG EROSION RATE

1 2 4 5 6 7 8 9 10 11 12 13

YEARS IN SERVICE-'- 2 MILS/YR AVG EROSION RATE

..,5 MILS/YR WORST CASE



WALL

0.50

0.40

030

0.201

0.10

NOMINAL WALL

S3WORSTCASE

-- B31.1 WALL_

I I II I I I I I0

0

oveo

pipe inspection program report2las2.1a pipe inspection program report 1987 kewaunee nuclear power...

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