ML17309A410
| ML17309A410 | |
| Person / Time | |
|---|---|
| Site: | Ginna  |
| Issue date: | 09/08/1987 |
| From: | Kober R ROCHESTER GAS & ELECTRIC CORP. |
| To: | Russell W NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
| References | |
| IEB-87-001, IEB-87-1, NUDOCS 8811290047 | |
| Download: ML17309A410 (150) | |
Text
0 DISTRIBUTJON DEMONSTRATION 0
AC~ CELEBRATED SYSTEM REGULATORY INFORMATION DISTRIBUTION SYSTEM (RIDS)
ACCESSION NBR:8811290047 DOC.DATE: 88/09/08 NOTARIZED! YES DOCKET FACIL:50-244 Robert Emmet Ginna Nuclear Plant, Unit 1, Rochester G 05000244 AUTH. NAME AUTHOR AFFILIATION KOBER,R.W. Rochester Gas 6 Electric Corp.
RECIP.NAME RECIPIENT AFFILIATION RUSSELL,W.T. Region 1, Ofc of the Director
SUBJECT:
Responds to NRC Bulletin 87-001 re thinning of pipe walls in nuclear power plants. 'R DISTRIBUTION CODE: IE11D COPIES RECEIVED:LTR ENCL SIZE: I TITLE: Bulletin Response (50 DKT)
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~4$ 'j~(i~ sso sr Ate ROCHESTER GAS AND ELECTRIC CORPORATION ~ 89 EAST AVENUE, ROCHESTER, N.Y. 14649-0001 TEEEPRONE AREA CODE 'sle 546 2700 September 8, 1987 Mr. William T. Russell Regional Administrator U.S. Nuclear Regulatory Commission Region 1 631 Park Avenue King of Prussia, PA 19406
Subject:
Nuclear Regulator Commission Bulletin 87-01 R.E. Ginna Nuclear Power Plant Docket No. 50-244
Dear Mr. Russell:
NRC Bulletin 87-'Ol requested information concerning thinning of pipe walls in nuclear power plants. Our responses to the bulletin are attached.
Very truly yours, R r . Kober Subscribed and sworn to me on this 8th day f Se tember 1987 Botany poMic in the State oi Ness Yorh MONROE COUNTY.
Commission Eatases Nov. 30, 1 &SS xc: USNRC Document Control Desk Desk (Original)
T. Polich< Ginna Resident Inspector 881l25'0047 880908 PDF< ADOCK 05000244 Q
PDC Qz- Il
Res onse to NRC IE Bulletin 87-01 question:
Identify the codes or standards to which the piping was designed and fabricated.
R~es onse:
All safety related and non-safety related piping systems were originally designed and fabricated to the requirements of USAS B31.1 Power Piping Code. Since the original construc-tion, repairs and/or modifications have been made which have been designed and fabricated to later codes, including ASME Section III. Reanalysis of critical safety related piping 2'," and larger was performed under the Seismic Upgrade Program which was reviewed by the NRC under SEP Topic III-6.
This program updated the piping analysis basis to criteria consistent with the ANSI 31.1 Code, including Summer 1973 addenda, with some amendments. This code edition remains as the current analysis basis for modifications performed on safety related piping. Non-safety related piping is designed and fabricated in accordance with the appropriate current edition of ANSI B31.1.
question:
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:
- 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
~Res onse:
Although one facet of the pipe wall thickness inspection has been ongoing for more than 10 years, the major portions of the Ginna inspection program have been put into place over the past five years. The various facets of the program were developed in response to either maintenance concerns at the Ginna plant or industry concerns associated with pipe wall degradation. Piping inspections have been performed 'hickness in areas previously identified .as potential problem areas, in areas which had become suspect from inspections or events at other plants, and in areas identified via regulatory information. Information sources used as references were:
NRC Bulletins and IE Information Notices, INPO Significant Event Reports or Significant Operating Experience Re~orts, and industry meetings and contacts.
8811290047
1 In the determination of inspection scopes, no attempt was made to selectively inspect isolated fittings. If an area of concern was identified, pipe and fittings subject to that concern were inspected. This methodology included duplicate trains and downstream piping subject to the same operating parameters. One exception to this approach occurred while performing post Surry event inspections in December 1986.
In order to provide the earliest possible information, these inspections were performed while the piping was hot. Due to the difficulty in performing "hot" inspections, the examina-tion locations were selectively determined by using engineering judgement while assuring that the most likely areas of wall thinning were included.
For the '87 outage, the scope of systems to be inspected was expanded to cover the majority of the high energy, carbon steel piping systems (including but not limited to FW Heater
& MSR Drains, Main Steam and Steam Generator Blowdown).
Since the intent of the '87 outage inspection program was to sample as many of these additional systems as practical, engineering judgement was used in selecting a manageable number of components for inspection. For the December '86 and the '87 outage inspections, the dominant criteria for selection of inspection locations was the piping geometry.
Based on experience at Ginna and in the industry, closely coupled fittings (such as combinations 'of tees, elbows, reducers, and fittings downstream of control valves) were considered to be the most likely place for erosion/corrosion to take place.
The frequency of inspections was determined by analysis of the results of data from previous outages. If inspection locations had yielded indications of significant wear, an engineering evaluation was performed to provide a basis for repair/replacement or an increased surveillance -at the next scheduled outage.
Except, for the turbine steam crossunder piping, which had been visually examined during a crawl-through, wall thick-ness measurements were made by UT examinations using current industiy-accepted techniques at the time of examination.
Repair or replacement. decisions prior to the '87 outage were based on an evaluation of the inspection results. For the
'87 outage, a Nonconformance Report (NCR) was written for all components which experienced a greater than 30% reduction from nominal wall thickness. The NCR's were formally disposi-tioned with replacement/repair and further inspection decisions based on the required minimum wall thickness. Disposition of NCR's considered the piping configuration, extent. of thinning, individual component service life, importance to safety and any other relevant conditions. If repair was not required, the next required inspection period was specified.
question:
For liquid-phase systems, state specifically whether the following factors have been considered in establishing your criteria for selecting points at which 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)
~Res onse:
Prior to the inspections influenced by the Surry pipe failure, the criteria for selection of locations for the wall thickness measurements. for liquid-phase systems was the same as that described in Item 2 above. For the inspections 'performed in December 1986 in response to the Surry incident, an inspection point selection criteria for liquid-phase flow systems was used that accounted for the previous Ginna Station experience and for some of the industry recognized factors affecting erosion/ corrosion. The major factor considered was the piping configuration. From previous Ginna Station and other utility inspection results, tees, valves elbows, reducers and components downstream of control had the highest incidence of degradation. Locations with closely coupled combinations of these fittings were considered to have a greater potential for erosion/corrosion than those fittings having greater than ten diameters of straight pipe between them. Other considerations which led to selection of inspection points were system temperature and fluid bulk velocity.
Inspection points were also chosen which represented a configuration similar to that at Surry or were at a similar point in the system. In addition, the December 1986 inspec-tions included portions of systems with temperatures similar to those at Surry. Since there was limited use of alloy piping materials in the original design of Ginna piping systems, piping material was not a major consideration in the inspection point selection criteria. Based on industry experience and the limited variation of the parameters within the suspect, Ginna systems, pH and 0 content in the system were not given major consideration fn selecting inspection points.
These same liquid-phase selection criteria were used to determine the locations for the expanded scope of systems inspected during the !87 refueling outage.
- 4. question:
Chronologically list and summarize the results of all inspec-tions that- have been performed, which were specifically conducted for the purpose of 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 determination.
- b. Describe what piping was examined .and how (e.g., describe the inspection instrument(s), test method, reference thickness, locations examined, means for locating measure-ment point(s) in subsequent inspections).
- c. Report thickness measurement results and note those that were identified as unacceptable and why.
- d. Describe actions already taken or planned for piping that has been found to have a nonconforming wall thick-ness. If you have performed a failure analysis, include the results of that analysis. Indicate whether, the actions involve repair or replacement, including any change of materials.
~Res onse:
- a. Rochester Gas and Electric's inspection program is designed to determine wall loss of 'carbon steel piping and components. The programmatic effort began in 1983 to specifically take baseline measurements on the pre-
.separator system. This effort has since expanded as described below. Inspection areas have been determined as described in the response to Question 42. Since the program to date has been "concern" oriented, the following describes the inspection program for the individual
, areas of interest.
(1) Routine Refueling Outage Inspection of the Turbine Crossunder Piping Between the High Pressure Turbine Sections and the Moisture Separator Reheaters.
I This inspection has been a routine maintenance item for approximately the last ten refueling outages.
This inspection consists of plant maintenance crews visually examining the pipe interior by crawling through the large diameter piping. The crossover piping has not had any evidence of pipe wall thick-ness reduction. However, the crossunder piping has had multiple areas of wall thickness degradation
and has been repaired. The procedure for repair consists of marking the areas where wall reduction was clearly evident (gouges, ripples, or depressions) and then making weld repair to bring the reduced areas back to the original wall thickness. No wall thickness measurements were taken during this routine maintenance.
Because of concern provided by a steam leak which developed in one of the expansion joints of a crossunder line, the areas of the pipe that are welded to the expansion diaphragm hinges were UT examined during the '87 refueling outage. The area of the leak was located, cut out, and replaced. To determine the extent of the problem, UT inspections were performed in similar locations on two of the other crossunder lines. These inspections found them to be in good condition. The leak was caused by corrosion resulting from poor geometry under the reinforcement pad and not due to general erosion/
corrosion wear. This area of the joint. is not visible during an ID inspection.
The preseparator system was installed in '83 to reduce the moisture content in the crossunders. A 70% removal effectiveness was determined through testing. Subsequent inspections indicate a reduced wear rate.
Turbine Extraction Steam Piping The extraction steam piping from the high pressure turbine to the feedwater heaters no. 4 and no. 5 was UT examined during the 1983 outage in response to the IE Information Notice 82-22 on the Oconee high pressure turbine exhaust line failure. Excessive wall reduction was found in some elbows, and they were replaced. Based on inspection results, compo-nents which had indications of significant wear were re-examined in the subsequent '84, '85, '86 S
'87 refueling outages and additional elbows and piping were replaced in the '86 outage. In the '86 refueling outage, the inspection area was expanded to include the extraction steam downcomers from the low pressure turbine in the condenser neck. No unusual wear was observed at that time.
Feedwater Pump Recirculation Piping The feedwater pump recirculation line to the condenser downstream of the flow control valves has experienced excessive vibration due to suspected flashing.
This piping was UT examined during the '86 refueling outage as part of the planned maintenance on the flow control valves and associated piping. Portions
of the piping were found to have excessive wall reduction and were replaced. Portions of the piping were re-examined in the subsequent. '87 refueling outage. In the '87 outage a new feed-water pump recirculation/bypass piping arrangement was installed that reduces to acceptable levels the service on the old'recirculation control valves to the condenser. This feedwater pump recirculation/
bypass line was given a .baseline thickness examina-tion during the outage.
(4) Turbine Moisture Separator Reheater 2nd Pass Drains to Feedwater Heater No. 5 A forced outage occurred in '86 due to the failure
'of an elbow downstream of the control valve in the drain line from the 2A .MSR to the 5B feedwater heater (Ref. LER 86-004). Informal UT readings were taken in other portions of the same line and in similar portions of the duplicate trains which confirmed that this was an isolated situation; should be noted that the elbow that failed had a it significantly shorter length of pipe between it the upstream control valve than all of the other and lines. The failed elbow was replaced with a higher schedule of a chrome alloy material. In the subsequent
'87 refueling outage the piping was re-examined and the control valve was relocated further upstream from the elbow. At the same time, the piping downstream of the control valves in the alternate dump lines to the condenser was examined, found to have excessive wall reduction, and was replaced.
(5) Feedwater Pump Suction Piping In response to the Surry pipe failure in the feedwater pump suction piping, UT examinations were taken in December '86 in geometrically similar portions of the Ginna feedwater piping and in portions of the feedwater heater drain system while the plant was at full power operating temperatures. All of the measurements indicated that the wall thicknesses were greater than 90% of the nominal wall thickness.
(6) 1987 Outage Program Expansion For the 1987 refueling outage, the piping inspections were expanded in response to the concerns identified regarding the Surry feedwater line break (IEN
- 86-106). The 299 components selected for UT examina-tion were a combination of those requiring re-examina-tion based on the results of previous inspections and of those systems, especially single phase liquid systems, that had not been suspected of wall
thinning problems prior to the Surry pipe failure.
This scope included piping in the Steam Generator Blowdown System, the remainder of the FW Heater Drains and the Moisture Separator-Reheater Drains, including the alternate dump to the condenser. The Main Steam system was added to the scope to include the remaining high energy carbon steel piping system. The Auxiliary Feedwater discharge lines were included because of their critical plant function and moderately severe operating conditions.'s a result of the inspections, portions of the Steam Generator Blowdown piping to the blowdown heat exchanger were replaced, along with portions of the Moisture Separator-Reheater drains alternate dump to the condenser. Many components inspected during 1987 have been selected for reinspection during the 1988 outage to trend the erosion/corrosion rate.
The piping which was examined is described in "a" above.
The method of performing the examinations is as follows.
The first step in the examination process is the removal of insulation, scale and any other materials that might interfere with the transmission of ultrasound. Next, the entire component (elbow, tee, pipe, or reducer) is laid out in grid fashion. Around the circumference of a given component, numbered rings are generated, and along the longitudinal axis lettered columns are generated.
The grid size is determined according to the component's diameter., For components equal to or less than 6" in diameter, grid sizes are 1 inch; greater than 6" and less than 12" in diameter, grids are 2 inch; and greater than 12" in diameter, grids are 3 inch. The first ring begins from the centerline of the upstream weld, and its distance from the weld is the same distance as the grid size. For example, if the component has a grid size of 2 inches, the first ring would begin 2 inches downstream from the centerline of the upstream weld. The, first data column follows the same rules for the reference location of a weld, typically the outside radius of an elbow, or, top center of a component. When two components are adjacent to each other, such as an elbow and a pipe (both components to be examined), the columns of the upstream component, are extrapolated to .the downstream component. In the case of a tee, the grids are laid out the same as for a pipe, with some variation. The on the run of a tee, leaving out the points where rings'egin the bull (branch) comes out. As the last ring is marked on the run, the next ring is marked on the bull. When there .is a change in flow direction or line size, the downstream component at which the flow change occurs will be examined for a distance of 12 inches. The 12 a inch distance may alternately be defined in terms of
0 given number of component diameters. For a representation of the component layout, refer to the drawings that follow the inspection data in Attachment 1.
After the component grid patterns have been laid out, the intersections of the grids are marked with a paint marker in order to provide locations for current and subsequent examinations. However, due to 'system tempera-tures and external surface conditions, the paint marks may not be visible for subsequent examinations.
Consequently, a consistent method of component layout pattern is maintained and documented for each component.
The following items are included in the component layout documentation: grid size, distance of the first ring from the upstream weld and direction the columns are lettered (clockwise or counterclockwise) in reference to flow in the component.
Once a component has been laid out, thickness readings are taken. The instruments used are the SONIC MARK I and the DMX-1. Transducers with frequencies ranging from 2.25 to 10.0 MHz and with diameters from .25" to
.5" are used. The selection of the transducer is deter-mined by the nominal wall and the component's geometry.
Calibration is performed for a thickness greater than the nominal thickness expected for a given component.
Nominal wall is determined from line specifications and/or previous history of the component.
Thickness readings of the component are then taken by 'a certified NDE technician, who either dictates the measured data to another technician, or he utilizes a data logger.
The data logger can be connected to either the SONIC or the DMX-1. This device stores the thickness readings of one or more components, and the data is later downloaded into a computer.
The next step is the data entry into the computer. When the data is recorded manually the data has to be entered manually, but when the data is recorded via the data logger, then it is entered through a serial interface.
Each component has a unique number assigned to it and is referred to as a summary number. This number becomes the file name of the data entered into the computer.
Grid profile information, type of component, pipe wall schedule and diameter are entered along with the transducer data.
With this information entered the file is compiled and spread sheets and color plots are generated. The color plot is used as a quick reference tool to locate a potential area of concern for a given component. The colors represent different percentages of the nominal wall remaining. The spread sheet is used for exact
thickness readings for specific grid locations. (Refer the sample plot and spread sheet that are attached as
'o Attachment 2)
- c. Thickness measurement results are reported chronologically in Attachment 1.
- d. Actions taken based on thickness measurement results are described in Attachment 1. The "Remarks" column will indicate next to a specific component, if it replaced or scheduled for further inspection.
was repaired, guestion:
Describe any plans either for revising the present or for developing new or addi;tional programs for monitoring pipe wall thickness.
R~es onse:
A significant level of pipe wall thickness inspections have already been made in both single and two phase flow systems as part of the existing Ginna Station program. To date, 501 component UT examinations have been performed, and the results have been recorded and appropriate actions taken.
The turbine crossunder piping has been routinely visually examined and repaired as necessary. 'eginning with the 87 refueling outage, the procedure for dispositioning non-conforming wall thickness measurements has been more closely controlled by processing a Non-Conformance Report using the plant QA program. The results from previous outages are being entered into the Ginna Station Maintenance In-Service Inspection Program data base system to facilitate identifying, tracking, and scheduling of future inspections.
The existing inspection program will be formalized further for both single and two phase flow systems consistent with the general guidelines of the NUMARC Norking Group on Piping Erosion/Corrosion Summary Report dated June ll, 1987.
Inspection sample size, inspection methods, acceptance guidelines, and program follow up represent the key areas of the recommended program. The scope of the present program's inspection points will be reviewed and evaluated. Considera-tion will be given to the need for expanding the number of inspection points and the selection of additional inspection points, if necessary, for single phase flow systems. An analytical computer model recognized by the utility industry will be utilized as a tool for evaluation of the suggested fittings, suggested piping locations, and key parameters identified in the NUMARC summary report (tabulated and included in Attachment 3).
For two phase flow systems, the appropriate portions of the single phase evaluation, previous Ginna Station experience,
and other utility industry recognized evaluation methods will be used. Included in this evaluation will be the determination of the schedule for the completion of the inspections for any additional points and reinspection of the existing points.
10
Attachment 1 to NRC IE Bulletin 87-01 Response (Item 4)
THE FOLLONINB IS A LIST OF COMPONENTS EXAMINED DURING THE 1983 OUTAGE AT SINNA STEAM EXTRACTION TO PRESEPARATOR B AND 4B L.P. HEATER A. 4 ELBOWS B. 2 PIPE SECTIONS C. j TEE STEAM EXTRACTION TO PRESEPARATOR A AND 4A L.P. HEATER A. 3 ELBOWS B. 2 PIPE SECTIONS C. T TEE STEAM EXTRACTION TO 5A Sc 5B H.P. HEATERS A. 6 ELBOWS R. 2 TEES OTAL COMPONENTS E: AS PART OF THE ACCEPTANCE OF COMPONENTS BEINB USED FOR A NEW PRESEPARATOR SYSTEM~ 40 ADDITIONAL COMPONENTS WERE INSPECTED. ALL INSTALLED COMPONENTS MET ALLOWABLE STANDANDS~HOWEVER, NO ATTEMPT WAS MADE TO TRACK SPECIFIC INSPECTION POINTS IN THE RECEIPT INSPECTION TO SPECIFIC LOCATIONS IN THE FINAL INSTALLED MODIFICATION.
RESULTS'F THICKNESS READINBS AT BINNA DURING 1983 OUTAGE 90 85/ NOM I NAL WALL THICKNESS STEAM EXTRACTION TQ PRESEPARATOR B cc 4B L.P.H.
3 STEAM EXTRACTION TO "'5A 8. 5B H. P. H.
80 70X NOMINAL WALL THICKNESS STEAM EXTRAt."TIP"'Q PRESEPARATOR B Sc 4B L. P. H.
2 STEAM EXTRACTION TO PRESEPARATOR A 5 4A L.P.H.
1 STEAM EXTRACTION TO 5A 8< 5B H. P. H.
70X NOMINAL WALL THICKNESS 4 STEAM EXTRACTION TQ PRESEPARATOR B 5 4B L. P. H.
STEAM EXTRACTIQN TQ PRESEPARATOR A 8c 4A L.P.H.
2 STEAM EXTRACTION TQ 5A 8. 5B H.P.H.
1983 OUTAGE THICKNESS READINGS AT BINNA STATION STEAM EXTRACTION TO PRESEPARATOR 8 AND 4B L P HEATER DRAWING M-21 RBZcE ID NO. COMPONENT PERCENTAGE REMARKS .
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 301015 1AD <0-8~
301025 2AD P, >90 301350 T 70-65 .580 301370 35 E 80-70 301390 37 E <65 .220 301410 38 <65 .220 301430 40 E 70-65 .260 STEAM EXTRACTION TO PRESEPARATOR A AND 4A L.P.HEATER DRAWING M-22 RGccE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER OF NOMINAL ER DRAMING THICKNESS 301705 1B. P >90 301715 28 P >90 302070 T 80-70 302090 . 35 E 80-70 302130 38 E <65 .200 REPLACED PRIOR TO END OF OUTAGE 302140 P REPLACED PRIOR TO END OF OUTAGE 302150 40 E <65 . 210 REPLACED PRIOR TO END OF OUTAGE STEAM EXTRACTION TO 5A Sc 5B H.P. HEATERS DRAWING M-75 RBZcE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 303090 T 90-85 303110 11 E >90 303130 13 E 70-65 .260 303140 14 E 80-70 303230 23 T >90 303240 24 E 90-85 303260 26 E 90-85 80 28 E <65 .240
THE FOLLOWING IS A LIST OF COMPONENTS EXAMINED DURING THE 1984 OUTAGE AT GINNA STEAM EXTRACTION TO PRESEPARATOR B AND 4B L.P. HEATER A. i9 ELBOWS R. 2 PIPE SECTIONS C. 2 TEES STEAM EXTRACTION TO PRESEPARATOR A AND 4A L.P HEATER A. 14 ELBOWS B. 2 PIPE SECTIONS C. 2 TEES STEAM EXTRACTION TO 5A h 5B H.P. HEATERS A. 5 ELBOWS B. 1 TEES TOTAL COMPONENTS
RESULTS OF THICKNESS READINGS AT BINNA DURING 1984 OUTAGE 90 85/ NOMINAL WALL THICKNESS 3 STEAM EXTRACTION TO PRESEPARATOR B 8( 4B L.P.H.
5 STEAM EXTRACTION TO 'PRESEPARATOR A h 4A L".'P.H.
2 STEAM EXTRACTION TO 5A Zc 5B H.P.H.
85 80/ NOMINA WALL THICKNESS 4 STEAM EXTRACTION TO PRESEPARATOR B Zc 4B L.P.H.
2 STEAM EXTRACTION TO PRESEPARATOR A 8c 4A L.P.H.
1 STEAM EXTRACTION TO 5A 8. 5B H. P. H.
80 70/ NOMINAL WALL THICKNESS 4 STEAM EXTRACTION TO PRESEPARATOR B 8c 4B L. P. H.
2 STEAM EXTRACTION TO PRESEPARATOR A S. 4A L. P H 3 STEAM EXTRACTION TO 5A 5 5B H P. H-
/ NOMINAL WALL THICKNESS STEAM EXTRACTION TO PRESEPARATOR B 5 4B L. P. H.
1 STEAM EXTRACTION TO PRESEPARATOR A 8( 4A L. P H.
1984 OUTAGE THICKNESS READINGS AT 'BINNA STATION STEAN EXTRACTION TO PRESEPARATOR B AND 4B L.P.,HEATER DRANING N-21 RB5E ID NO. COMPONENT PERCENTAGE RENARKS SUNNARY PER TYPE OF NOMINAL NUNBER DRAWING THICKNESS 30101 1A P 85-80 301020 2 E >90 301025 2A P 85-80 301030 E 80-70 301050 5 E >90 301070 7 E >90 301120 301130 li 12 E
E
'90-85 90-85 301160 15 E >90 301180 3 17 E >90 30 21 E 90-85 60 24 E >90 3o1280 26 E >90 301300 28 E >90 301320 30 T 85-80 301350 T 80-70 301370 E 80-70 301390 37 E (65 222 301410'01430 38 E <65 . ~ 227 40 E 80-70 301470 4p E >90 301490 46 E >90 301510 48 E 85-80 STEAM EXTRACTION TO PRESEPARATOR A AND 4A L P.HEATER DRANINB N-22 RBSE ID NO. COMPONENT PERCENTAGE ~
RENARKS SUNNARY PER TYPE OF NONI NAL NUMBER DRAWING THICKNESS 301705 1B P >90 301715 2B P 90-85 301720 E >90 301740 5 E >90 760 7 E 90-85 80 E 90-85 00 11 E >90 301850 15 E >90 301900 1'9 E >90
J )
M EXTRACTION TO PRESEPARATOR A AND ~L P HEATER DRANINB '~~ .CONT RB8cE ID NO. REMARKS
SUMMARY
PER NUMBER DRAWING 301920 21 E >90 301980 2b E 90-85 302030 30 E >90 302050 32 E >90 302070 33 T 70-b5 450 302090 35 E 80-Wo 302110 mi7 T 80-70 302130 38 E 90-85 302150 40 E 85-80 STEAM EXTRACTION TO 5A h 5B H.P. =HEATERS "BRAMINB ~~
RB8cE ID NO. COMPONENT PERCENTABE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER I DRAW NB THICKNESS 303090 T 80-70 10 11 E 90-85 30 13 E 90-85 140 14 E 80-70 3032b0 2b E 80-70 303280 28 E 85-80
THE FOLLOWING IS A LIST OF COMPONENTS EXAMINED DURINB THE 1985 OUTAGE AT BINNA STEAM EXTRACTION TO PRESEPARATOR B AND 4B L.P HEATER A. 4 ELBOWS B. 2 PIPE SECTIONS STEAM EXTRACTION TO PRESEPARATOR A AND 4A L P HEATER
- 4. 4 ELBOWS B- 2 PIPE SECTIONS STEAM EXTRACTION TO 5A h 5B H.P. HEATERS A. 4 ELBOWS 1b TOTAL COMPONENTS
RESULTS OF THICKNESS READINGS AT BINNA DURING i'F85 OUTAGE 90 85X NOMINAL WALL THICKNESS 2 STEAM EXTRACTION TO PRESEPARATOR A Sc 4A L.P.H.
'85 -"80X NOMINAL WALL THICKNESS 1 STEAM EXTRACTION TO PRESEPARATOR A 8. 4A L.P.H.
1 STEAM EXTRACTION TO 5A 8c 5B H ~ P. H.
80 70X NOMINAL WALL THICKNESS 1 STEAM EXTRACTION TO PRESEPARATOR B 5 4B L.P.H.
2 STEAM EXTRACTION TO 5A Zc 5B H.P.H.
70K NOMINAL WALL THICKNESS STEAM EXTRACTION TO PRESEPARATOR B Zc 4B L. P. H.
STEAM EXTRACTION TO 5A 5 5B H-P.H.
1985'UTAGE THICKNESS READINGS AT BINNA STATION
'- ~
P1 STEAM EXTRACTION TO PRESEPARATOR B AND 4B L.P.HEATER ..DRAWING M-21 P.
RGS(E ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 301015 1A P 80-70 301020 2 E >90 301025 2A P 85-80 301390 37 E (65 225 301430 40 E <65 .236 301440. 41 P >90 STEAM EXTRACTION TO PRESEPARATOR A AND 4A L P HEATER DRAWING M-22
'kE ID NO. COMPONENT PERCENTAGE REMARKS ARY PER TYPE OF NOMINAL MBER DRAWING TH I CKNESS 301705 1B P 85-80 301715 28 >90 301720 E >90 301900 19 E >90 302130 38 E 90-85 302150 40 E 90-85 STEAM EXTRACTION TO 5A Sc 5B H.P. HEATERS DRAWING M-75 RB8cE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 303130 E 80-70 303140 14 E 80-70 303260 26 E 85-80 303280 28 E <65 .238
THE FOLLOWING IS A LIST QF COMPONENTS EXAMINED DURING THE 1986 OUTAGE AT GINNA BYPASS TO CONDENSER (CV-18) 'EEDWATER
=
kw A. 7 ELBOWS B. 2 REDUCERS C. 8 PIPE SECTIONS FEEDNATER BYPASS TO CONDENSER (CV-19>
A. 4 ELBOWS B. .2 REDUCERS C. 4 PIPE SECTIQNS STEAN EXTRACTION TO PRESEPARATOR B AND 4B L.P. HEATER A. 6 ELBOWS B. 4 PIPE SECTIONS C. i TEE N EXTRACTION TO PRESEPARATOR A AND 4A L.P. HEATER A. 2 ELBOWS STEAN EXTRACTION TO 5A Sc 5B H.P. HEATERS A 3 ELBOWS B. 2 PIPE SECTION C. i TEE LQM PRESSURE DOWN COMERS A. 7 PIPE SECTIONS 53 TOTAL COMPONENTS
RESULTS OF THICKNESS READINGS AT BINNA DURING 1986 OUTAGE 90 85/ NOMINAL WALL THICKNESS 1 FEEDWATER RECIRC CV-18 1 FEEDWATER RECIRC CV-19 LOW PRESSURE DOWNCOMER 85 80/ NOMINAL WALL THICKNESS 2 FEEDWATER RECI RC CV-18 1 FEEDWATER REC IRC CV-19 1 STEAM EXTRACTION TO 5A 8. SB H. P. H.
1 LOW PRESSURE DOWNCOMER 80 70/ NOMINAL WALL THICKNESS 5 FEEDWATER RECIRC CV-18 1 STEAM EXTRACTION TO PRESEPARATOR B 5 4B L.P.H.
STEAM EXTRACTION TO SA 8. 5B H.P.H.
LOW PRESSURE DOWNCOMER 70X NOMINAL MALL THICKNESS 6 FEEDWATER REC IRC CV-18 5 FEEDWATER RECIRC CV-1'P 1 STEAM EXTRACTION TO PRESEPARATOR B 5: 4B L.P.H.
1 STEAM EXTRACTION TO PRESEPARATOR A 8c 4A L.P.H.
STEAM EXTRACTION TO 5A 8c SB H.P.H-2 LOW PRESSURE DOWNCOMER
1986 OUTAGE THICKNESS READINGS AT BINNA STATION FEED WATER BYPASS TO 'CONDENSER (OLD CV-18) .""'~DRAWING CV-18 RBEcE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 300300 29 R <65 . 212 REPLACED END OF 86 OUTAGE 300310 30 P <65 ~ 214 REPLACED END OF 86 OUTAGE 300320 31 E <65 . 273 REPLACED END OF 86 OUTAGE 300330 32 P <65 . 186 REPLACED END OF 86 OUTAGE 300340 33 E <65 .253 REPLACED END OF 86 OUTAGE 300350 34 E 80-70 REPLACED END OF 86 OUTAGE 300360 35 P 85-80 REPLACED END OF 86 OUTAGE 300370 36 E 85-80 REPLACED END OF 86 OUTAGE 300380 37 P >90 REPLACED END OF 86 OUTAGE 300390 38 E 80-70 REPLACED END OF 86 OUTAGE 300400 39 P 90-85 10 40 E 80-70 20 41 P 80-70 0430 42 E >90 300440 43 P 70-65 . 291 300450 44 R >90 300460 45 P 80-70 FEED WATER BYPASS TO CONDENSER (OLD CV-19) DRAWING CV-19 RG8cE ID NQ. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE QF NOMINAL NUMBER DRAWING THICKNESS 300550 9 E 85-80 300790 33 R <65 ~ 062 REPLACED END QF 86 OUTAGE 300800 34 E <65 .088 REPLACED END OF 86 OUTAGE 300810 35 P <65 .243 REPLACED END OF 86 OUTAGE 300820 36 E 90-85 REPLACED END OF 86 OUTAGE 300830 37 P >90 REPL'ACED END OF 86 OUTAGE 300840 38 E 70-65 .284 300850 P .70-65 ~ 284 300860 40 >90 300870 41 P >90 13
M EXTRACTION TO PRESEPARATOR B AND 4B L P HEATER DRAWING M-21 RGSE ID NQ. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 301020 2 E >90 301 160 15 E >90 301350 33 T 80-70
'301370 35 E 70-65 .260 301380 36 P >90 301390 37 E >90 BASELINE 301400 7A P >90 BASELINE 301410 38 E >90 BASELINE-0] 420 P >90 +,
+
BASELINE 301430 40 E >90 ~ BASELINE 301440 41 P >'90
+ THESE COMPONENTS WERE REPLACED AT THE BEGINNING OF THE 1986 OUTAGE STEAM EXTRACTION TO PRESEPARATOR A AND 4A L.P.HEATER DRAWING M-22
.E ID NO. COMPONENT PERCENTAGE REMARKS ARY PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 301720 >90 301900 19 >90 STEAM EXTRACTION TO 5A Sc '5B H.P HEATERS DRAWING M-75 RGSE ID NG. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 303090 T 70-65 .380 303130 13 E <65 .240 303140 14 E 80-70 303150 15 P 85-80 303280 28 E <65 303290 29 P >90
PRESSURE DOWN COMER RGZ(E ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS DCiA86 A P 9'0-85 DC1886 B P 85-80 DCiC86 C P 80-70 DciD86 D P 90-85 DCiE86 E P 90-85 DCiF86 F P <65 .224 DCiG86 G P <65 . i~i
THE FQLLQNINB IS A LIST QF COMPONENTS EXAMINED DURING DECEMBER 19'8b AT BINNA HEATERS 4A h 4B TO FEEDMATER SUCTION A. 2 ELBOWS B. 3 PIPE SECTIONS C. 2 TEES FEEDNATER SUCTION TO PUMPS A h B A. 4 ELBOWS B. 7 PIPE SECTOINS 5A H. P.H. DRAIN TO 4A L.P.H.
A. 3 TEES 5B H.P.H. DRAIN TO 4B L.P.H.
3 TEES 24 TOTAL COMPONENTS
DECEMBER 1986 THICKNESS READINGS AT BINNA STATION ERS 4A Sc 4B TO FEEDMATER SUCTION RBEcE ID NO. COMPONENT PERCENTAGE 'REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS
,. ~,, -m',. << ~: ~mid,A'el&a w..~i)gf< r~ia 205110 11 T >90
,205230 23 T >90 205250 25 T >90 205260 26 P >90 205280 28 P >90 20 310 E >90 205330 33 E >90 205340 34 P >90 FEEDMATER SUCTION TO PUMPS A 5 B RGZcE
SUMMARY
ID NO.
PER
'ERCENTAGE COMPONENT TYPE OF NOMINAL REMARKS NUMBER DRANING TH I CKNESS 020 2 P >90 30 E >90 40 4 P >90 206050 5 E >90 206060 6 P >90 206110 11 P >90 206120 12 E >90 206140 14 P >90 206250 25 P >90 206260 E >90 206270 27 P >90 5A H. P. H. DRAIN TO 4A L. P. H. M-41 A RGZcE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE QF NOMINAL NUMBER DRAWING THICKNESS 290210 2l T >90 290230 23 T >90 290250 25 T >90 5B H. P. H. DRAIN TO 4B L. P. H. N-41B
%E ID NO. COMPONENT PERCENTAGE REMARKS jARY PER TYPE OF NOMINAL BER DRAWING THICKNESS 291210 60 T >90 Pc7 1 T >90 291250 64 T >90
THE FOLLOWING IS A LIST OF CONPONENTS EXANINED DURING THE 1987 OUTAGE AT GINNA NSR 1A & iB 2ND PASS DRAIN TO 5A H P H. h CONDENSER A.' ELBOWS B. 10 PIPE SECTIONS C. 3 REDUCERS D. S'EES NSR 2A & 2B 2ND PASS DRAIN TO 5B H.P.H. & CONDENSER A. 6 ELBOWS B. 9 PIPE SECTIONS C. 3 REDUCERS D. 6 TEES 1As 2As & 3A L.P.H. DRAINS A. 10 PIPE SECTIONS 1 REDUCER 9 TEES iBs 2Bs & 38 L.P.H. DRAINS A. 2 ELBOWS B. 11 PIPE SECTIONS C. 1 REDUCER D. 7 TEES NSR 1 As iB s 2A Sc 2B TO HEATER DRAIN TANK A. 2 ELBOWS B~ 3 PIPE SECTIONS FEEDWATER PUNP BYPASS A- 24 ELBOWS B 18 PIPE SECTIONS C. 5 REDUCERS DE 5 TEES WATER BYPASS TO CONDENSER (CV-18) 11 ELBOWS B. 2 REDUCERS C. 11 PIPE SECTIONS
WATER BYPASS TO CONDENSER (CV-19)
A. 12 ELBOWS B. 2 REDUCERS C. 11 PIPE SECTIONS STEAM EXTRACTION TO PRESEPARATOR B AND 4B L.P HEATER'.
3 ELBOWS B. 1 TEE STEAM EXTRACTION TO PRESEPARATOR A AND 4A L P HEATER A 3 ELBOWS B. 1 TEE STEAM EXTRACTION TO 5A Sc 5B H.P. HEATERS A. 5 ELBOWS R., i PIPE SECTION 2 TEES S/8 BLOWDOWN TO BLOWDOWN HEAT EXCHANGER A. 4 ELBOWS B. 14 PIPE SECTIONS C. 4 REDUCERS D. 2 TEES THIS INCLUDES BASELINE ON COMPONENTS THAT WERE REPLACED S/6 BLOWDOWN TO BLOWDOWN TANK HEADER A. 12 ELBOWS B. 26 PIPE SECTIONS C. 2 REDUCERS PRESEPARATOR A Sc B DRAIN TO. HEATER DRAIN TANK A. 3 ELBOWS B. 5 PIPE SECTIONS C. 1 TEE l9
AUX. FEEDMATER PUMP A TO F.M. DISCHARGE LINES 1"ELBOM PIPE SECTIONS AUX. FEEDMATER PUMP B TO F N DISCHARBE LINES A 1 ELBOW B. 2 PIPE SECTIONS TURBINE DRIVEN AUX FEEDMATER PUMP TO F M DISCHARGE LINES A. 2 P I PE SECTIONS MAIN STEAM FROM S/6 B A. 1 ELBOW MAIN STEAM TO TURBINE A. 1 ELBOW 1 PIPE SECTION 299 TOTAL COMPONENTS
RESULTS QF THICKNESS READINGS AT BINNA DURING "1987 OUTAGE 9'0 85/ NOMINAL MALL THICKNESS c
1 MSR 1A 8( 1B 2ND PASS DRAIN TO 5A H.P.H. Zc.CONDENSER 4 .-MSR 2A Sc 2B 2ND PASS'DRAIN TO 5B H.P.H. 'O'CONDENSER FEEDWATER RECIRC CV-18
'EEDWATER RECIRC CV-19 1 STEAM EXTRACTION TO 5A 8c 5B H P. H.
3 S/G BLOWDOWN TO BLOWDOWN HEAT EXCHANGER 8 S/8 BLOWDOWN TO BLOWDOWN TANK HEADER 2 PRESEPARATOR A Zc B DRAIN TO HEATER DRAIN TANK 1 AUX F. W. PUMP A TQ F. W. DISCHARGE LINES 1 AUX F. W. PUMP B TO F. W. DISCHARGE LINES 80/ NOMINAL MALL THICKNESS 2 MSR 2A Cc 2B 2ND PASS DRAIN TO 5B H.P.H. cc CONDENSER 1 MSR 1A, 1B, 2A h 2B TO HEATER DRAIN TANK 1 STEAM EXTRACTION TO 5A 4 5B H.P.H.
S/G BLOWDOWN TO BLOWDOWN TANK HEADER TURBINE DRIVE AUX F. W. PUMP TQ DISCHARGE LINES 80 70/ NOMINAL WALL THICKNESS MSR 1A Rc iB 2ND PASS DRAIN TO 5A H. P. H. Sc CONDENSER 2 MSR 2A 5 2B 2ND PASS DRAIN TO 5B H.P.H. Zc CONDENSER FEEDWATER RECIRC CV-18 FEEDWATER REC IRC CV-19 1 STEAM EXTRACTION TO PRESEPARATOR B Zc 4B L.P.H.
1 STEAM EXTRACTION TO PRESEPARATOR A Zc 4A L P H 2 STEAM EXTRACTION TO 5A Zc 5B H.P.H ~
2 S/G BLOWDOWN TQ BLOWDOWN HEAT EXCHANGER 1 S/G BLOWDOWN TO BLOWDOWN TANK HEADER 70/ NOMINAL MALL THICKNESS MSR 1A ~4c iB 2ND PASS DRAIN TO 5A H. P. H. 8c CONDENSER MSR 2A 8c 2B 2ND PASS DRAIN TO 5B H.P.H. Sc CONDENSER FEEDWATER RECI RC CV-18 FEEDWATER REC I RC CV-19 STEAM EXTRACTION TO PRESEPARATOR B 5 4B L P. H.
STEAM EXTRACTION TO PRESEPARATOR A 5 4A L ~ P. H STEAM EXTRACTIQN TQ 5A 8( 5B H. P. H.
S/G BLOWDOWN TO BLOWDOWN HEAT EXCHANGER S/G BLOWDOWN TQ BLOWDOWN TANK HEADER
1987 OUTAGE THICKNESS READINGS AT'BINNA STATION MSR iA h iB 2ND PASS DRAIN TO 5A H.P H. 8c CONDESER DRAWING M-12A RBSE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING TH I CKNESS 222230 21A R >90 222240 22 E >90 REPLACED END OF 87 OUTAGE 222250 23 P >90 REPLACED END OF 87 OUTAGE 222330 31 R >90 222340 32 T >90 222350 33 T >90 222352 33A P >90 222357 338 T >90 222360 34 P >90 222370 35 T >90 222380 36 P >90 390 37 T >90 00 38 P >9'0 10 39 T >90 222415 39A P >90 222420 40 T >90 222920 90 T >90 223020 99 T NO READINBS WERE TAKEN DUE TO WELD OVERLAY~ REPLACED 87 OUTAGE 223030 100 P 80-70 REPLACED END OF 87 OUTAGE 223040 101 E 70-65 (.298) REPLACED END OF 87 OUTAGE 223050 102 P 90-85 REPLACED END OF 87 OUTAGE 223060 103 E (65 <.274> REPLACED END OF 87 OUTAGE 223070 104 P 80-70 REPLACED END OF 87 OUTAGE 223080 105 E 80-70 REEXAMINE DURING 88 OUTAGE 223090 106 P 80-70 REEXAMINE DURING 88 OUTAGE 223095 106A R >90 MSR 2A tk 2B 2ND PASS DRAIN TO 5B H.P.H. Sc CONDENSER DRAWING M-12B RGccE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 222490 47 R >90 222500 48 E 80-70 ELBOW WAS REPLACED SUMMER 1986 WITH SCHEDULE 120. LINE SCHEDULE IS 80 REEXAMINE DURING 88 OUTAGE
.10 P >90 520 50 E >90 222530 51 P 90-85 REEXAMINE DURING 88 OUTAGE 222680 66 T >90
2A h 2B 2ND PASS DRAIN TO 5B H P H h CONDENSER DRAWING N-12B CONT RGScE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 222690 67 T >90 222700'22710 68 P >90 69 T >90 222720 70 P '>90 222730 71 T >90 222800 78 R >90 222810 79 E >9G RFPLACED END OF 87 OUTAGE 222820 80 P 90-85 'EPLACED "END <OF~87 OUTAGE 222830 81 T NQ READINGS WERE TAKEN DUE TO WELD OVERLAY~ REPLACED 87 OUTAGE 222840 82 P 85-80 REPLACED END OF 87 OUTAGE 222850 83 E <65 (.254) REPLACED END OF 87 OUTAGE 222860 84 P >90 REPLACED END OF 87 OUTAGE 222870 85 E 90-85 REPLACED END OF 87 OUTAGE 222880 86 P 80-70 REPLACED END OF 87 OUTAGE 222890 87 E 85-80 REPLACED END OF 87 OUTAGE 222900 88 P 90-85 REEXAMINE DURING 88 OUTAGE 905 88A R >90 10 89 T >90 iA, 2A~ 3A, L. P. H. DRAINS DRAWING M-19 RB8cE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 234180 18 T >90 234190 19 P >90 234200 20 T >90 234210 21 P >90 234220 22 T >90 234230 23 P >90 234240 24 T >90 234250 25 P >90 234260 26 T >90 234270 27 P >90 234340 34 R >90 234345 34A >90 234350 35 T >90 234355 35A P >90 234370 37 T >90 234380 38 P >90 234510 51 T >90 520 52 P >90
~30 53 T >90 540 54 P >90
2B Sc 3B L P.H. DRAINS DRANING M-20 RGScE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAMING THICKNESS 235160 16 P >90 235170 17 E '>90
'235180 18 P >'90 235190 19 E >90 235200 20 P >90 235210 21 T >90 A3L NAQ P >90
,235230 23 T >90 235740 >90 235250 25 T >90 235260 26 P >90 235325 32A R >90 235330 P >90 235340 34 T >90 235350 35 P )90 235370 37 T >90 235380 38 P >90
.5510 51 T >90 20 52 P >90 3Q 53 T )9Q 235540 54 P >90 MSR 1 Av iBv 2A h 2B TO HEATER DRAIN TANK DRAMING M-33 RGhE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 262030 E )90 262040 4 P >9Q 262055 5A P >90 262060 6 E >90 262070 7 P 85-80 REEXAMINE DURING 88 OUTAGE FEEDMATER PUMP BYPASS DRAWING M-92 RG'CcE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 281020 2 E BASELINE 281030 P BASELINE 281040 E BASELINE 050 5 P BASELINE bo 6 E BASELINE 070 7 P BASELINE 281090 P BASELINE 281110 11 P BASELINE
DWATER PUMP BYPASS DRAWING M-92 CONTINUED RG8cE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 281130 13 R BASELINE 281140 14 P BASELINE 281150 15 E BASELINE 281160 16 P BASELINE 281180 18 E BASELINE 281190 19 P BASELINE 28$ ~0& E BASELINE 281210 21 P BASELINE 281230 P BASELINE 281250 P BASELINE 281270 27 R BASELINE 281280 28 P BASELINE 281290 29'0 R BASELINE 281300 T BASELINE 281310 31 E BASELINE 281320 32 T BASELINE 281330 33 P BASELINE 281340 34 E BASELINE 50 35 E BASELINE 60 36 P BASELINE 1370 37 E BASELINE 281380 38 E BASELINE 281390 39 P BASELINE 281400 40 E BASELINE 281410 41 P BASELINE 281420 E BASELINE 281440 44 E BASELINE 281460 46 E BASELINE 281480 48 E BASELINE 281490 49 E BASELINE 281500 50 P BASELINE 281520 52 T BASELINE 281530 53 R BASELINE 281540 54 T BASELINE 281560 56 E BASELINE 281600 60 E BASELINE 281620 BASELINE 281640 64 E BASELINE 281680 68 T 'ASELINE 281700 70 E BASELINE 281730 73 R BASELINE 281750 75 E BASELINE 281760 76 P BASELINE 770 77 E BASELINE NOTE: FEEDWATER BYPASS LINE IS A NEW INSTALLATION DONE DURING THE 87 OUTAGE
WATER BYPASS TO CONDENSER (OLD CV-18) DRAWING CV-18 RGSE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 300220 22 E >90 300230 23 P >90
.'00240 24 E >90 300250 25 P >90 300260 26 E 90-85 300270 27 P 90-85 300280 E 300300 29 R >90 3003}0 P >90 300320 31 E >90 300330 32 P >90 300340 33 E >90 300350 34 E >90 300360 35 P >90 300370 36 E >90 300380 37 P >90 300390 38 E >90 3 400 P 80-70 10 40 E 80-70 20 41 P 80-70 300430 42 E >90 300440 43 P 70-65 ( ~ 299) 300450 R 90-85 300460 45 P 90-85 NOTE:IT HAS NOT BEEN DECIDED IF THESE COMPONENTS WILL BE REEXAMINED IN 1988. THE FEEDWATER BYPASS SYSTEM THAT WAS INSTALLED IN 1987 SHOULD TAKE OF THIS EROSION PROBLEM.
ALSO THE NEW FEEDWATER BYPASS HAS REPLACED COMPONENTS 1 THROUGH 20 FEED WATER BYPASS TO CONDENSER (OLD CV-19) DRAWING CV-19 RG8cE ID NO. COMPONENT PERCENTAGE ,REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 300480 E >90 300490 P >90 300640 18 E >90 300650 19 P >90 300660 20 E >90 300670 21 P >90 80 22 E >90 90 CD P 90-85 700 24 E >90 300710 25 P >90 300720 26 E 80-70
WATER BYPASS TO CONDENSER (OLD CV-19) DRAWING CV-19 CONTINUED RGSE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 300730 27 P >90 300740 28 E '90-85 300750 29 P 90-85 300760 30 E >90 300770 31 E >90 300790 33 R >90 300800 34 E >90
,300810 35 P >90
'300820 36 F SO-7O 300830 37 P >90 300840 38 E 80-70 300850 P <65 (. 270) 300860 40 R >90 300870 41 P >90 NOTE: IT HAS NOT BEEN DECIDED IF THESE COMPONENTS WILL BE REEXAMINED IN,1988. THE FEEDWATER BYPASS SYSTEM THAT WAS INSTALLED IN 1987 SHOULD TAKE OF THIS EROSION PROBLEM.
ALSO THE NEW FEEDWATER BYPASS HAS REPLACED COMPONENTS 3
,THROUGH 16.
STEAM EXTRACTION TO PRESEPARATOR B AND 4B L.P.HEATER DRAWING M-21 RGZcE ID NO ~ COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 301020 2 E >90 301 160 15 E >90 301350 33 T 80-70 REEXAMINE DURING 88 OUTAGE 301370 35 E 70-65 (. 260) REEXAMINE DURING 88 OUTAGE STEAM EXTRACTION TO PRESEPARATOR A AND 4A L.P. HEATER DRAWING M-22 RGhE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 301720 3 E >90 301900 19 E >90 302070 33 T 80-70 REEXAMINE DURING 88 OUTAGE 302090 35 E <65 (. 223) REEXAMINE DURING 88 OUTAGE
M EXTRACTION TO 5B H P. HEATERS .DRANINB M-75 RB8cE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 303090 9 T <65 ( ~ 244) . REEXAMINE DURING;88 OUTAGE 303100 10 P 80-70 'REEXAMINE'DURING'88 OUTAGE 303110 11 E 80-70 REEXAMINE .DURING 88 OUTAGE 303130 13 E <65 (.237) REEXAMINE 'DURING 88 OUTAGE 303140 14 E 70-65 (.247) REEXAMINE DURING 88 OUTAGE 303230 23 T 90-85 REEXAMINE DURING 88 OUTAGE E 85-80 REEXAMINE DURING 88 OUTAGE 303280 28 E <65 (.232) REEXAMINE. DURING 88 OUTAGE S/8 BLOMDONN TO BLONDONN HEAT EXCHANGER DRAWING M-87 RBS(E ID NO. COMPONENT PERCENTAGE 'REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 304080 8 P >90 304100 10 P <65 ( ~ 120)"
10 P BASELINE 12 P <65 (- 121) 12 P BASELINE 304130 13 R 90-85 13 R BASELINE 304210 21 P >90 304230 P <65 (. 115) 23 P BASELINE 304240 24 P 80-70 COMPONENT HAS BEEN ELIMINATED 304250 25 T 70-65 (. 208) 25 T BASELINE 304260 26 P 80-70 26 P BASELINE 304270 27 E >90 304280 28 P >90 304290 E >90 304300 30 P >90 304320 32 E 90-85 REEXAMINE DURING 88 OUTAGE 304330 P , >90 304340 34 R >90 304350 35 E 90-85 I I REEXAM NE'DUR NG 88 'OUTAGE 304360 36 R 4 X 10 REDUCER CAN NOT BE PROPERLY LAID:OUT~.HONERVER SCAN SHOWS NO 'SIGN OF NEAR THESE COMPONENTS MERE REPLACED DURING 87 OUTAGE AND BASELINE DATA WAS TAKEN
BLOWDOWN LINES INTERNIDIATE BLDG. DRAWING M-88A RBSE ID NO. CONPONENT PERCENTAGE RENARKS
SUMMARY
PER TYPE OF NONINAL NUNBER DRAWING THICKNESS
- tl 304420 COMPONENT IS A FORGED ELBOW
"'AND~CAN"NOT"BE LAID"OUT,'"HOWEVER SCAN SHOWS NINIMUN WALL OF .. 180
'WILL'"REEXANINE"DURING 88 OUTAGE 304440 CONPONENT IS A FORGED ELBOW AND CAN NOT BE LAID OUT, HOWEVER SCAN SHOWS MINIMUM WAi L OF . 1
.WILL REEXANINE,DURING 88 OUTAGE S/G BLOWDOWN TO BLOWDOWN TANK HEADER DRAWING N-88B RBKcE ID NO. CONPONENT PERCENTAGE REMARKS SUNNARY PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS
+~o 29 31 P
P
>90
>90 304730 P >90 304750 35 P >'90 304770 37 P >90 304790 39 P '0-70 REEXANINE DURING 88 OUTAGE 304820 42 P >90 304840 44 P >90 304860 46 R >90 304865 46A E <65 (.208) OUTSIDE RADIUS OF ELBOW CAN NOT BE EXAMINED DUE TO RESTRICTIONS, REEXANINE DURING 88 OUTAGE 304870 47 P 85-80 REEXANINE DURING 88 OUTAGE 304880 48 E 90-85 REEXANINE DURING 88 OUTAGE 304890 49 P >90 304900 50 E 85-80 REEXAMINE DURING 88 OUTAGE 304920 52 E 90-85 REEXANINE DURING 88 OUTAGE 304930 53 P >90 305220 82 P >90 305240 84 P >90 305260 86 P . >90 305280 88 P >90 305300 90 'P >90 305320 92 P >'90 305340 360 "90 94 96 P, P
P
>90 70-65 (. 142)
>90 REEXANINE DURING 88 OUTAGE 410 101 P 90-85 305430 103 R >90
SLOWDOWN TO BLOWDOWN TANK HEADER DRAWING M-88B CONTINUED RG~~E ID NO. COMPONENT PERCENT ABE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 305440 104 70-65 (. 229) OUTSIDE RADIUS OF ELBOW CAN NOT
'~" BE EXAMINED"DUE'~TO'-RESTRICTIONS~
REEXAMINE DURING 88 OUTAGE 305450 105 P >90 305460 106 E 90-85 DURING 88 OUTAGE I'EEXAMINE 305470 107 P 90-85 REEXAMINE DURING 88 OUTAGE 305480 108 E >90 305490 109 P 90-85 REEXAMINE DURING 88,OUTAGE 305500 110 E >90 305510 111 P >90 305520 112 E 90-85 REEXAMINE DURING 88 OUTAGE 305540 114 E >90 305550 115 P 90-85 REEXAMINE DURING 88 OUTAGE NOTE: MANY ELBOW COMPONENTS CAN NOT BE EXAMINED DUE TO GEOMETRY. ELBOWS ARE FORGED AND DO NOT LEND THEMSELVES TO LAYOUT OR U.T. SCANNING EPARATOR A h B DRAIN TO HEATER DRAIN TANK DRAWING M-46B 5E ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 328160 16 T >90 328240 P >90 UPSTREAM PORTION OF PIPE 328245 P >90 DOWNSTREAM PORTION OF PIPE 328250 25 E >90 328260 26 P >90 328270 27 E 90-85 REEXAMINE DURING 88 OUTAGE 328280 28 P >90 328290 29 E 90-85 REEXAMINE DURNIB 88 OUTAGE 328300 30 P >90 AUX. F.M PUMP A TO F N. DISCHARGE LINES "DRAWING M-48 RBSE ID NO. COMPONENT PERCENTAGE REMARKS
SUMMARY
PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 320240 25 E 90-85 REEXAMINE DURING 88 OUTAGE 320264 26A P >90 320430 43 P >90 UPSTREAM PORTION OF PIPE 435 43 >90 DOWNSTREAM PORTION OF PIPE
F.I4. PUMP B TO F N. DISCHARGE LINES DRANINB M-49 RGSE ID NO. COMPONENT PERCENTAGE RENARKS SUNMARY PER TYPE OF NON INAL NUNBER DRAW INB THICKNESS 323200 20 E >90 A t~
323210 21 ,P >90 ~
323420 42 P 9'0-85 REEXANINE DURING 88 OUTAGE TURBINE DRIVEN AUX F.N PUMP TO F.N DISCHARGE LINES '.DRAMINB-47 RG8<E ID NO. COMPONENT PERCENTAGE REMARKS
- SUNMARY PER TYPE OF NONINAL NUMBER DRAWING THICKNESS 327560 56 P >90 UPSTREAN PORTION OF PIPE 327565 56 P >90 DOWNSTREAM PORTION OF PIPE 327880 88 P 85-80 REEXANINE DURING 88 OUTAGE MAIN STEAN FROM S/6 A 5 B DRANINB N-70 RG5E , ID NO. COMPONENT PERCENTAGE REMARKS NARY PER TYPE OF NONINAL ER DRAWING THICKNESS 370020 2 MAIN STEAN TO TURBINE DRAWING N-72 RBSE ID NO. CONPONENT PERCENTAGE RENARKS SUNNARY PER TYPE OF NOMINAL NUMBER DRAWING THICKNESS 372140 372150 14 15 E
P '90 >90
LOW PRESSURE DOWNCOMERS 1C 1D TOP VIEW
0
~ a 0 t" v NO. DESCRIPTI FILE NAME f/VO'Rs coHuz/sFR 1 4'IPE ~ 300010 90 ELBOW 300020 3 6~ PIPE 300030 4 90 ELBOW 300040 5 6~ PIPE 300050 6 90 ELBOW 300060 7 3'IPE 300070 8 90 ELBOW 300080 9 2'IPE 300090 10 VALVE 4061 300100 11 90 ELBOW 300110 g ty 12 3~ PIPE 300120
+C~~ +C" 13 90 ELBOW 300130 14 4'IPE 300140 15 90 ELBOW 300150 16 9'IPE 300160 17 90 ELBOW 300170 18 4'IPE 300180 19 90 ELBOW 300190 20 27'IPE 300200 21 51~ PIPE 300210 22 90 ELBOW 300220 23 12~ PIPE 300230 24 90 ELBOW 300240 25 8% PIPE 300250 26 45 ELBOW 300260 27 1'IPE 300270 28 45 ELBOW 300280 28A VALVE 4262 300290 29 4"TO 6"REDUCER 300300 30 2~ PIPE 300310 31 45 ELBOW 300320 32 i~ PIPE 300330 33 45 ELBOW 300340 45 ELBOW 300350 iv PIPE 300360
~LB 45 ELBOW 300370 4'IPE 300380 8 38 90 ELBOW 300390 39 2'IPE 300400 40 45 ELBOM 300410 41 1'IPE 300420 42 45 ELBOW 300430 43 4'IPE 300440 44 6"TO 4"REDUCER 300450 45 2'IPE 300460
gaJYRS coecrgpr Jgg NO DESCRIPT I 0 FILE NAME 3'IPE 300470 2 90 ELBOW 300480 3 8~ PIPE 300490
~~~c~
eo 4 90 ELBOW 300500 5 3'IPE 300510 6 90 ELBOW 300520 7 2~ PIPE 300530 8 VALVE 4060 300540 9 90 Et BOW 300550
" zc "~~~ce C
10 3~ PIPE 300560 li
~
4'o 90 ELBOW 300570 61 PIPE 300580 13 90 ELBOW 300590 14 4~ PIPE 300600 15 90 ELBOW 300610 16 27~ PIPE 300620
.17 40~ PIPE 300630 18 45 ELBOW 300640 19 1~ PIPE 300650 20 45 ELBOW 300660 21 1'IPE 300670 22 45 300680
-23 ii PI>ELBOW E 300690 45 ELBOW 300700 25 11~ PIPE 300710 90 ELBOW 300720 3 10~ PIPE 300730 28 90 ELBOM 300740 10~ PIPE 300750 30 45 ELBOW 300760 31 45 ELBOW 300770 VALVE 4363 300780 4"TO 6"REDUC ER 300790 90 ELBOW 300800, 4~ PIPE 300810 36* 45 ELBOW 300820 3'IPE 300830 38 45 ELBOW 300840
>5 39 3~ PIPE 300850 40 "6"TO 4"REDUC ER 300860 Fg H ~ggQjgy~ 41 2'IPE 300870
+~~ 0 D)S'cog g~
HEATERS 4A & 4B TO FEEDWATER SUCTION OWf. 055 55 d 57 1d 15 5d 20
FEEDWATER SUCTION TO PUNPS A 5 8 27A dd Odd.dd 3970
~ 1 7 Cddt.dd
NSR 1A 6 18 2ND PASS DRAIN TO 5A H. P. H. 5 CONDENSER 38 39 39A 40 5A
~40A HEATER 37 32 31 16 18~~
14 11
.6 12~
o~ 21 2$ A f / 99 103 1pp 1p2
~o 17 ~ 19 94 18 ~
106 gO&4
~~
~
98A 90 95 r
96 r~ia+
NSR 2A 5 2B 2ND PASS DRAIN TO 5B H.P.H. 5 CONDENSER 70~ 71
~ 72 5B N HEA1ER 50 68 65 eg 59~/ 61 60 o
REDUCERS 52 89 ~VS
N-19 1A, 2A 5 3A LoP H. DRAINS 10X8 20 REDUCER
\
'l6. ~M 17 16 15 8
'l8
'3 6"
24 29 45/ 7 8~ Q 7A 6
2A 2 4 5 1A 52 30 10X8 55 RED 50 56 2A 3369 CV-34 1A ~op 40 Sp~
ex6 lg~
RED 4107 8 34 36 3371 eX6 CY-8 34A 35A RFll 10X6
M-20 18~ BB & 3B L. P.H. DRAINS j
Cp oAgp~
2B qg ~. <0~S
@ED r
Mp 6
/ s 02 21 15 Vy 50 g4 10~8 5$ 20%4g~5 E eg gX6 RED r,iOS
~ >6 22 2 pg70 eve ~py
@K'
'N-2 i STEAN EXTRACTION TO PRESEPARATOR B ~~3 IB L. P. H CONT. ON M-22 45 47 o ia 28 27 /'
30 45'7A 21 28
~ 38 33 i .
3g 20A 1A 18
M-22 STEAM EXTRACTION TO PRESEPARATOR A u4 4A L. P. H.
35 CONT. ON M-21 37 32
- 37 4p.
45'8 15A 18 p
"~+.
1903 39 1902 28A 4 +444 Q 14 25A 27 1901 24 5801 1900 20
bfBR 1 Ar 18'A 4 28 To HEATER DRAXhl TANK HFATER DR4N TANK N
$0
>>r lR CONl; ON M-3l l8 CONT. ON 12 M-3'l
$3 15 54 Lt~MS 2A CONT. ON Lf-32 28 CONl; ON Q-32
N-4i A 5A H. P H. DRAIN TO 4A L P H.
8 27 QRhlH ThHK iiC4AFR
M 4KB 5B He Pa He DRAIN TO'B Le Pe Ha 58 42 47 70 vl
)
i X 57 t
52
~+
2 HQTER oem 70 TANK
N-46B PRESEPARATOR A 5 B DRAIN TO HEATER DRAIN TANK OA co+'.055 M~ 1 0
coMr.oN ll~-I 8
HEAPS/
ss~ 5853 / 56 DRAIN 7ANK 2+
5955 1916 64 1810 72 1909 27 73 1912 6 79 70 82 81 vs
N-47 TURBINE DRIVEN AUX F W. PUMP TO DISCHARGE LINES IO SO-IB 4005 4004 l
~q~ 00NI.Pg M~
75 75
~m Ceres 55
~L ~ 11A 11 10 74 I5 12 J
71 72 41 7524 FW HFAIKR SO"A" 4257 50
~
55 4
/'005
N-48 AUX F M PUNP A TO DISCHARGE LINES SC 1A~
14 /,(
u-47 2-1/2" 452 12~
11~ 4dd0 10 4007
~47 400O Pi oat.m
~49~
L I I
Sl d2
N-49 AUX F. N. PUMP B TO DI SCHARGE LINES IDSO 1e rrr u-o Qs 27 2-1/2' 60 1g 14 4000B 15 44 4484 1Q 1$
6 ~~
6 4 ~ 4010 47 Oe 00Nl' 8 Lt 50 i,
1 4NO
NAINSTEAN FRON S/6 A 5 B SG 1B PEH 402 CONf. Otl Ll-73 COH1; ON@-71 SG 1A I SKAM GENERhTOR 1A
N-72 NAINSTEAN TO TURBINE (i
20 21 17 WALL CONT. ON Il-71 CONf. ON
M-75 STEAM EXTRACTION TO 5A ~~~ 58 H.P.H.
CONT. ON 15
~200"0200 25 ~
HEAIER 5B 55'15A mdd 5517A 5
20
'-z 21 20 t ddI dd 5514k 10 10
N-87 8/G BLOWDOWN TO BLOWDOWN HEAT EXCHANGER HX 4x10 REDUCER 32 1
cotK ON 95198 9517A 3ll 27 21 2I I 19 9516B 6 8
9519A 26 5772 13 3x2 REDUCER
l5l-88A S/G BLOhlDQMN LINES INTERNEDIATE BLDG.
CONf. ON M-88-2 f
I I
28 PEN 321 I
5701 IIAII 1/4II 80 z) 5 ~
10 2ll 12 79 78 II8II 54 f 5" 5702 5737 45I 62 j/
70 72 20 75 74 65 69
hi-88B S/G BLOWDOWN TO BLOWDOWN TANK HEADER IIEIDEE 109 452 113 107 L
'IDE 115 31 CONT. ON 97 90
~
95160 9510A 5710 94 54 102 92 57109 101 2x4 REDUCER 100
/
5709 57095
N-92 FEEDNATER PUNP BYPASS 7 34 l/
l l
2 7\ 72 I
70 78 CON;OH Ll-Q1 ee corn.ov M-So
Attachment 2 to NRC IE Bulletin 87-01 Response (Ref. Item 4b)
LAYOUT FQR U,T, THICKNESS READINGS 7 5 6 C B 6 4 1 2 3 B
B C p~
c E
FLOV 3 D E
6 7 A I B C g H D E F
FILE: SAMPLE. PLT DESCRIPTION: 90 DEGREE ELBOW
REFERENCE:
UPSTREAM WELD SCHEDULE: 80 LOCATION OF FIRST RING: .5 INCHES PIPE OD: 6.625 DISTANCE BETWEEN DATA RINGS: 1 NOMINAL THICKNESS: . 432 2 1' 4 3 5 U A T B S C R D 9 Q E 10 P F 10 0 G 11 12 N H 12 13 M I 13 L J K K 14 15 16 17 17 FLOW DIRECTION: DOWNSTREAM INCREMENT DIRECTION: CW ERI 5%3 KB ER 90 90 85 85 80 80 70 70 65 < 65 RESTRICTION
DATA FILE: QNPLE PLT ELHN ANGLE '0 COANENT DESCRIPTION: 90 DEGREE ELAN SQKDULE MMER: 80 NNIW. PIPE SILE: 6 QJIER DIANETER t, 6.625 PIPE THICKNESS: .432 RAN6E: A -U CIRCNFERENTIAL LENGTH RANGE: 1 - 18 NQSERS OF TRANSITION RINGS: 1 AND 18 FUN DIRECTION: MIISTREAN INCRBENT DIRECTIN: N REFERENCE FRN NICH RINGS HILL BE NEASURED -: UPSTREAN IJELD LOCATION QF FIRST DATA RING (FRN REFERENCE): .5 DISTANCE BETMEEN DATA RINGS !. 1 3 4 10 A 0.4850 0.3820 0.3820 0.3820 0.3610. 0.3400 . 0.2970 0.1540 0.0920 0.2970 B 0.4480 0.4370 0.4340 0.4340 0.3820 0.3820 0.3400 0.2970 0.2970 0.3400 C 0.4190 0.4140 0.4160 0.4190 0.4110 0.3820 0.3820 0.3400 0.3400 0. 3820 D 0.4460 0.4230 0.4170 0.4380 0.4130 0.4000 0.3820 0.3820 0.3820 0.3820 E 0.4380 0.4490 0.4550 0.4340 0.4310 0.4240 0.4370 0.4450 0. 4620 0. 4190 F 0.4760 0.4590 0. 4600 0. 4690 0,4480 0. 4740 0. 4580 0. 4510 0.4800 0.4710 6 0. 4900 0. 4780 0. 4690 0. 4730 0. 4620 0. 4960 0. 4540 0. 4790 0,4580 0. 4620 H 0. 5090 0. 4890 0. 4900 0. 4850 0.4980 0.4520 0.4560 0.4520 0.4570 0.4680 I 0.4930 0.4880 0.4450 0.4640 0.4600 0.4380 0.4440 0,4470 0.4420 0.4460 J 0. 4840 0. 4840 0.4950 0. 4500 O. 4450 0. 4410 0. 4620 0. 4430 0. 4510 0.4520 K 0.'4970 0.4740 0.4750 0.4780 0.4750 0.4730 0.4800 0.4990 0.4920 0.4770 L 0.5240 -1.0000 -1.0000 -1.0000 0,5270 0.5250 0.5000 0.5160 0.5210 0.5090 N 0,5270 -1. 0000 "1. 0000 "1. 0000 0. 4880 0. 5010 0. 4980 0. 5000 0. 5120 0. 5070 N 0,4700 -1.0000'1.0000 -1.0000", 0,4660'.4540 0. 4550 0. 4720 0. 4470 0 0.4820 0.4790 +- 0.4590.>.. 0.4620 '. O.h530 0.4830 0,4580 0.4620'.4600 0.4580 . 0.4580 0.4570 P 0.4540 0.4440 0.4380" ". 0.4440-. 0.4650 0. 4590 0.4570 0.4620 0.4540 0, 0. 4540 0. 4540 0.4520 0.4380 0.4420 0.4400 0. 4580 0.4480. 0.4330 0. 4350 R 0. 4430 0. 4250 0. 4250 0. 4290>> 0.4370 0.4320 0.3820 0.3820 0.3820 0.3820 S 0.4430 0.4550 0.4180" 0.4140" 0.4040 0,3820'.3820 0.3400 0. 3400 0. 3820 T 0. 4400 0. 4400 0. 4060 0. 4180 0. 3820 0. 3820 0.3400 0.2970 0.2970 0.3400 U 0.4400 0.4230 0.3820 0.3820 0.3610 0.3400 0.2970 0. 1540 0. 1000 0.2970
12 13 15 16 17 18 A 0. 3400 0. 3610 0. 3820 0. 4360 0. 4270 0. 4370 0. 4300 0. 4420 B 0. 3820 0. 3820 0. 4270 0. 4390 0. 4330 0. 42M 0. 4250 0. 4260 C 0.3820 0. 4080 0. 4200 0. 4130 0,3970 0. 4190 0. 3990 0. 4150 D 0. 4790 0.4160 0. 4040 0. 4060 0. 4150 0. 4320 0. 4190 0. 4340 E 0. 4590 0. 4190 0. 4560 0. 4390 0. 4520 0. 4300 0. 4320 0. 4360 F 0. 4640 0.4540 0. 4530 0. 5120 0. 4980 0. 4520 0. 4670 0. 4390 6 0.4510 0.4470 0.4470 0.4450 0.4530 0.4510 0.4540 0,4420 H 0.4S20 0.4470 0.4450 0.4390 0.4400 0.4390 0.4370 0.4360 I 0. 4530 0.4760 0.4370 0. 4730 0. 4430 0. 4480 0,4430 0,4240 J 0.4520 0.4420 0.4600 0.4410 0.4480 0.4480 0.4380 0.4430 K 0. 4840 0. 4820 0. 4750 0. 5220 0. 4780 0. 4850 0. 4900 0. 4940 L 0.5170 0.5100 0.4930 0.5020 0.5110 0.5020 0.5960 0.5070
- 0. 4880 0. 4920 0.4950 0. 4800 0. 4840 0.4%0 0. 5280 0. 4850 .,
H 0. 4670 0. 4650 0.4920 0. 4410 0. 4550 0. 4660 0. 5050 0.5260 0 0.4620 0.4620 0.4560 0.4510 0.5140 0.4550 0.5030 0.4540 P 0.4540 0.4540 0.4530 0.4730 0.4780 0.4620 0.5000 0.4660 0 0.4330 0.4470 0.4S40 0.4540 0.4S40 0.4560 0.4S70 0.4560 R 0.4540 0.4540 0.4650 0.4550 0.4580 0.4570 0.4570 0.4S40 S 0.3820 0.4220 0.4620 0.4210 0.4030 0.4270 0.4230 0.4460 T 0.3820 0.3820 0.4110 0.4060 0.4030 0.3990 0.4080 0.4450 U 0.3400 0.3610 0.3820 0.3820 0,4340 0.4540 0.4350 0.4700
Attachment 3 TABLE 1 SUGGESTED FITTINGS Closely Coupled Fittings or Configurations Entrant Tee, Combining Tee, Splitting Tee 90'lbow Reducer/Expander Straight Section of Pipe Downstream of:
- Reducer
- Flow Control/Throttling Valve Restricting Orifices Multiple Thermowells, etc.
TABLE 2 SUGGESTED PIPING LOCATIONS Feedwater Suction Feedwater Discharge Heater Drain Pump Discharge Condensate from FW Heater 4 HPCI (BWR)
Attachment 3.
KEBLE'.
KEY'ARAMETERS =.
C.S. pipin~ 6'comgozrents; malar. gar-onater.chromium. content pK, 02 content'luid'.
temperature "
I ocal/Bu?k.. flaw rate.;=
Piping; product- geometzy factar;: .
Joint configurations (backing. rings, etc
. )
NOTE: Information extracted. from EPRI Workshop Information -
(April .14-15) and. EPRI Report'P-'3944 '-
a fl $
> "~'
0