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.
2.2 1984 Refueling Outage
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.
2.3 1985 Refueling 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.
2.4 1986 Refueling Outage
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.
2.5 1987 Refueling Outage
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
No. of Components Inspected
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
No. of Components Inspected
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
No. of Components Inspected
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
LINE/PORTION OF LINE REPLACED
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
LINE/PORTION OF LINE REPLACED
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
LINE/PORTION OF LINE REPLACED
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
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 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
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 > 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
AVERAGE PERCENT THINNED
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
AVERAGE PERCENT THINNED
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
AVERAGE PERCENT THINNED
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
14B
0.60
0.50
0.40
030
0.20
0.10
013
4
BLEED STEAM TO FW HTR 12" LINE
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
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
BLEED STEAM TO FW HTR 16" LINE
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
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
+ COMPONENT MINIMUM WALL THICKNESS
A AVERAGE MINIMUM WALL THICKNESS
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