ML17221A396

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Rev 1 to St Lucie Unit 1,Extraction Steam Piping Insp Program Guidelines.
ML17221A396
Person / Time
Site: Saint Lucie NextEra Energy icon.png
Issue date: 01/28/1987
From:
FLORIDA POWER & LIGHT CO.
To:
Shared Package
ML17221A395 List:
References
PROC-870128, NUDOCS 8709160137
Download: ML17221A396 (51)
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Text

ATTACHMENTA ST. LUCIE UNIT 1 EXTRACTION STEAM PIPING INSPECTION PROGRAM GUIDELINES JANUARY 23, 1937 REVISION 1 8709160137 870910 PDR ADQCK 05000335 8 PDR

EXTRACTION STEAM PIPING INSPECTION PROGRAM GUIDELINES TABLE OF CONTENTS SECTION DESCRIPTION PAGE (S)

BACKGROUND/PURPOSE INSPECTION SCOPE III METHOD QF INSPECTION IV SCREENING CRITERIA INSPECTION PROCESS .

REQUIRED DOCUMENTATION 6-7 TABLE I LIST OF PIPING/FITTINGS REQUIRING INSPECTION ] goal/ I SKETCH 1 GENERIC MAPPING AREAS ELBOWS SKETCH 2 GENERIC MAPPING AREAS BRANCH CONNECTIONS SKETCH 3 GENERIC MAPPING AREAS TEES DRAWINGS:

.REF. I/M 8770-4427~ CONDENSER MARK-UP 8770-G-125, SHS. BF-M-4 AND BF-M-5, FEEDWATER PIPING ISOMETRIC MARK-UP 8770-G-125, SHS. C-E-2 AND C-E-10, CONDENSATE PIPING ISOMETRIC MARK UP 8770 G 125~ SH MS L 1 MAIN STEAM PIPING ISOMETRIC B-43, BLOWDQWN PIPING ISOMETRIC 8770-G-125, SHS. HD-J-1 AND HD-0-2 HEATER DRAIN PIPING ISOMETRIC

  • DRAWINGS ARE NOT INCLUDED BUT ARE AVAILABLE AT fPL.

EXTRACTION STEAM PIPING INSPECTION PROGRAM GUIDELINES I. BACKGROUND/PURPOSE A RUPTURE OF AN EXTRACTION STEAM LINE. ON UNIT 1 DURING CYCLE 7 RESULTED IN FORCED OUTAGE AND A LOSS OF APPROXIMATELY 39 FULL POWER HOURS. AN EXAMINATION OF THE FAILED PIPE AND A FOLLOW-UP ENGINEERING EVALUATION CONCLUDED THAT EROSION/CORROSION WAS THE FAILURE MECHANISM. EROSION/CORROSION IS AN INDUSTRY WIDE PROBLEM

.THAT IS UNIQUE TO WET STEAM PIPING SYSTEMS. EROSION/CORROSION IS AN ACCELERATED FORM OF CORROSION INDUCED BY FLOW DUE TO THE BREAKDOWN OF A PROTECTIVE OXIDE FILM FROM THE MATERIAL'S SURFACE.

DURING THE FORCED OUTAGE, THE PIPING DOWNSTREAM QF THE FAILED SECTION WAS ALSO INSPECTED AND FOUND TO BE ERODED. BECAUSE OF THE PIPE FAILURE OCCURENCE AND FOLLOW-UP INSPECTION RESULTS, THE NEED FOR AN INSPECTION AND REPAIR PROGRAM WAS DETERMINED TO EXIST.

THE'URPOSE OF THIS DOCUMENT IS TO PROVIDE SPECIFIC INSPECTION GUIDELINES AND ACCEPTANCE CRITERIA FOR UNIT 1 WET STEAM PIPING SYSTEMS TO ADDRESS EROSION/CORROSION CONCERNS.

ALSO, IN LIGHT OF THE RECENT SURREY PLANT PIPING FAILURE INCIDENT, REPRESENTATIVE FITTINGS AND PIPING FROM OTHER HIGH ENERGY SYSTEMS SUCH AS FEEDWATER, BLOWDOWN AND HEATER DRAIN ARE INCLUDED WITHIN THE SCOPE OF THESE INSPECTIONS.

II. INSPECTION SCOPE BECAUSE OF THE SIGNIFICANT AMOUNT OF WET STEAM PIPING IN THE ST.

LUCIE NUCLEAR POWER PLANT ~ A METHOD FOR PRIOR ITIZING'HE INSPECTION POINTS WAS FIRST DEVELOPED THIS METHOD REQUIRED THE CALCULATION QF EROSION RATES FOR REPRESENTATIVE, PIPING CONFIGURATIONS" AND CONDITIONS. THE RATE QF EROSION/CORROSION IN WET STEAM PIPING IS A FUNCTION OF A NUMBER OF FACTORS INCLUDING:

PERCENT MOISTURE MATERIAL COMPOSITIQN pH AND WATER CHEMISTRY TEMPERATURE OXYGEN FLOW PATH GEOMETRY FLOW VELOCITY HAVING DETERMINED THE EROSION RATES, THE PIPING MINIMUM WALL AND WEAR ALLOWANCES WERE THEN CALCULATED FINALLYs A LIST PRIORITIZING THOSE PIPING CONFIGURATIONS WITH THE HIGHEST EROSION RATES AND SHORTEST PREDICTED TIME TO VIOLATE MINIMUM WALL

~ ~

EXTRACTION STEAM PIPING INSPECTION PROGRAM GUIDELINES II. INSPECTION SCOPE (CONT ')

THICKNESS REQUIREMENTS WAS GENERATED AND USED TO IDENTIFY REQUIRED INSPECTION POINTS. IN GENERAL, THE INSPECTION AREAS ARE AS FOLLOWS:

1 . CROSSUNDER PIPING BRANCH CONNECTIONS TO THE 4A AND 4B FEEDWATER HEATERS

2. 4A AND 4B FEEDWATER HEATER EXTRACTION STEAM LINE TRAP BRANCHES
3. 4A AND 4B FEEDWATER HEATER EXTRACTION STEAM PIPING ELBOWS PLUS REPRESENTATIVE STRAIGHT PIPING
4. 5B FEEDWATER HEATER EXTRACTION STEAM LINE TRAP BRANCHES S. MSR SSVC TEE CONNECTION TO THE NUMBER 5B FEEDWATER HEATER EXTRACTION STEAM LINE PLUS RESPECTIVE DOWNSTREAM ELBOW
6. REPRESENTATIVE 58 FEEDWATER HEATER EXTRACTION STEAM LINE ELBOW
7. 2A OR 2B FEEDWATER HEATER EXTRACTION STEAM FABRICATED ELBOW CONNECTION IN THE CONDENSER
8. STRAIGHT PIPING DOWNSTREAM OF THE 3A~5B AND 4A~48 FEEDWATER EXTRACTION STEAM LINE NON-RETURN VALVES
9. FEEDWATER RECIRCULATION PIPING AND ELBOWS DOWNSTREAM OF THE RECIRCULATION CONTROL VALVE
10. CONDENSATE PUMP FULL FLOW RECIRCULATION PIPING AND ELBOW DOWNSTREAM OF THE RECIRCULATION CONTROL VALVE
11. FEEDWATER PIPING AND BRANCH CONNECTION DOWNSTREAM OF THE

,FEEDWATER REGULATING VALVES

12. HEATER DRAIN TIE IN BRANCH CONNECTION TO THE CONDENSATE SYSTEM
13. MSR HEMI-HEAD DRAIN BRANCH CONNECTION
14. MSR SHELL SIDE DRAIN PIPING BRANCH CONNECTION
15. BLOWDOWN PIPING AND ELBOW DOWNSTREAM OF PRESSURE CONTROL VALVE
16. MAIN STEAM PIPING TEE CONNECTION THE SPECIFIC REQUIRED INSPECTION POINTS ARE LISTED IN TABLE I ALONG WITH A UNIQUE DESIGNATION NUMBER AND DRAWING REFERENCE. THE ELEVEN PLANT DRAWINGS LISTED IN THE TABLE OF CONTENTS ARE ATTACHED AND HAVE BEEN MARKED-UP TO SHOW THE SPECIFIC FITTINGS AND PIPING TO BE INSPECTED.

EXTRACTION STEAM PIPING INSPECTION PROGRAM GUIDELINES I II. METHOD OF INSPECTION INSPECTION IS TO BE CONDUCTED USING AN ULTRASONIC DEVICE TO MEASURE WALL THICKNESS. GENERALLY, ONE ULTRASONIC WALL THICKNESS READING WILL BE REQUIRED FOR EVERY 2" X 2" AREA ON PIPING AND FITTINGS LARGER THAN b" NOMINAL PIPE SIZE, AND FOR EVERY 1" X 1" AREA FOR'IPING AND FITTINGS b" NOMINAL PIPE SIZE AND LESS.

FOR EACH INSPECTION POINT LISTED IN TABLE 1 p AN "INSPECTION SCOPE" IS GIVEN. THE INSPECTION SCOPE FOR EACH GENERIC FITTING TYPE, I.E., 45 DEGREE ELBOWS, 90 DEGREE ELBOWS, TEES AND BRANCH CONNECTIONS, IS SHOWN IN DETAIL IN SKETCHES 1,2,3 AND 4. THESE SKETCHES INDICATE HOW EACH CONFIGURATION TYPE IS GENERALLY TO BE MAPPED. THE SKETCHES ALSO INDICATE APPROXIMATELY HOW THE INSPECTION REPORT MAPS SHOULD APPEAR.

I V. SCREENING CRITERIA TABLE 1 PROVIDES A WALL THICKNESS VALUE FOR EACH EXTRACTION STEAM FITTING OR PIPING SECTION TO BE INSPECTED. IF INSPECTION RESULTS INDICATE THAT ALL ULTRASONIC TEST READINGS ARE EQUAL TO QR GREATER THAN THE VALUE SPECIFIED, THEN NO REPAIR OR REPLACEMENT ACTIVITIES WILL BE REQUIRED. IF ANY ULTRASONIC TEST RESULT IS LESS THAN THE VALUE SPECIFIED, THEN AN NCR IS TO'E GENERATED WHICH INCLUDES THE INSPECTION REPORT FOR THE FITTING OR PIPING SECTION AND INDICATES THE SCREENING CRITERIA VALUE VIOLATED.

FOR OTHER HIGH ENERGY FLUID SYSTEMS, SCREENING CRITERIA IS NOT PROVIDED. FOR THESE CASES', THE INSPECTION REPORT PACKAGE SHALL BE REVIEWED BY ENGINEERING PRIOR TQ REPLACING INSULATIQN OR REPAINT ING.

V. INSPECTION FLOW CHART THE FOLLOWING. IS A DESCRIPTION OF THE GENERAL PROCESS REQUIRED F6R THE INSPECTION OF EACH FITTING OR PIPING SECTION:

ERECT SCAFFOLDING (WHERE REQUIRED)

REMOVE PIPE INSULATION AND SAVE (WHERE FEASIBLE)

OR REMOVE PAINT COATING PREPARE PIPE SURFACE FQR UT INSPECTION (WIRE BRUSH TO REMOVE SCALE AND OXIDATION)

EXTRACTION STEAM PIPING INSPECTION PROGRAM GUI DEL INES V. INSPECTION FLOWCHART (CONT ')

MAP AREA TO BE INSPECTED IN ACCORDANCE WITH TABLE I AND THE APPROPRIATE SKETCH DETAIL DOCUMENT UT INSPECTION REPORT IF ALL UT RESULTS'REPARE RESULTS ARE EQUAL TO OR GREATER THAN THE SCREENING CRITERIA B. PREPARE INSPECTION REPORT AND NCR IF ANY UT RESULT IS LESS THAN THE SCREENING VALUE C. IF NO SCREENING VALUE IS PROVIDED, SUBMIT INSPECTION REPORT TO ENGINEERING RaV i (ENGINEERING TO ADVISE IF NCR REQUIRED)

ENGINEERING REVIEW AND DISPOSITION NCR (WHEN APPLICABLE)

REPAIR IF REQUIRED NOTE: PC/M REQUIRED IF REPLACEMENT OF PIPING/FITTINGS INVOLVED IN REPAIR REINSTALL PIPE INSULATION (OR REPAINT) ] REV REMOVE SCAFFOLDING VI I. REQUIRED DOCUMENTATION AN INSPECTION REPORT SHALL BE PREPARED FOR EACH INSPECTION POINT.

THIS INSPECTION REPORT SHALL INCLUDE, AS A MINIMUM, THE FOLLOWING INFORMATION:

1. DRAWING NUMBER
2. PIPING/FITTING LABEL (AS LISTED IN TABLE I )
3. SCREENING CRITERIA
4. UT MAP (S) AS INDICATES BY TABLE I AND THE APPROPRIATE SKETCH DETAIL

~ ~

I

EXTRACTION STEAM PIPING INSPECTION PROGRAM GUIDELINES

5. NCR NUMBER (IF NCR REQUIRED)
6. ENGINEERING SIGN-OFF FOR INSPECTION REPORTS TO DOCUMENT WHETHER NCRS ARE OR ARE NOT REQUIRED

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ATTACHMENT8 ST. LUCIE UNIT 1 INSPECTION PROGRAM RESULTS

SUMMARY

APRIL 28, 1987

Summar of Unit 1 Refuelin Outa e Pi in Ins ections and Activities Attachment A provided the inspection program which was designed to detect erosion/corrosion degradation of piping in high energy systems. The systems included in the scope of the inspection program were extraction steam and main steam (to address the concerns of the subject REA), condensate, feedwater, blowdown and heater drain (to address concerns resulting from the Surry incident).

The method of inspection involved ultrasonic mapping of the piping and fitting areas suspected of being susceptible to erosion/corrosion. The following summarizes our findings and corrective actions for each of the systems inspected:

Blowdown: Seven fitting/piping locations were inspected. No signs of erosion/corrosion were evident.

Feedwater: Three fitting/piping locations were inspected, including one similar in configuration to the failed section involved in the Surrey incident.

No signs of erosion/corrosion were evident.

Main Steam: One branch fitting at the main steam header was inspected. No signs of erosion/corrosion were evident.

Extraction Steam Piping: These lines, as anticipated, were the only lines to show signs of erosion/corrosion. Portions of the extraction steam piping associated with the number 2 through number 5 feedwater heaters were inspected, and activities are summarized as follows:

Number 2 Feedwater Heaters: Two fabricated elbows (located in condenser) were inspected. Both elbows showed signs of erosion/corrosion damage. No corrective action was specified, since these fittings are expected to survive through Cycle 10 (i.e., given actual erosion rates, encroachment on code minimum wall thickness would not be expected until approximately Cycle 11).

Number 3 Feedwater Heaters: Three fittings/piping locations were examined. Some minor erosion/corrosion was detected, however, piping wall thicknesses are still within manufacturers tolerances.

Number. 0 Feedwater Heaters: All elbows and several sections of straight piping were inspected (a total of 30 examination reports).

These lines were expected to have sustained the most serious erosion/corrosion damage, and inspection results verified this expectation. As a result of inpsection data review, eight 20" elbows were replaced. along with approximately 30'f associated piping. These fittings and piping were replaced since erosion had either encroached on code minimum wall thickness or would have resulted in violation of code minimum values within the next operating cycle. All fittings and piping were upgraded to chromium-molybdenum alloy steel which is expected to survive "life-of-plant" from the viewpoint of erosion/corr osion resistance (Reference PC/M 117-186).

MCI1:5

Summar (cont'd)

The balance of number 0 feedwater heater extraction steam line piping and fittings are in most cases severely eroded, and replacement of all remaining elbows and much of the piping is predicted within the next three to four cycles of operation.

Number 5 Feedwater Heaters: Five fitting/piping locations were examined, and extensive erosion/corrosion, was indicated by examination results. In the most severe cases, it was determined that, based upon actual erosion/corrosion rates, the fittings would survive an additional cycle of operation before code minimum wall thickness would be a concern. The number 5 feedwater heater extraction. steam lines will make up the majority of the inspection program for the l987 ref ueling outage, since 100%a examination of fittings will be recommended. Also, based on the erosion/corrosion rates, new chromium-molybdenum piping and fittings should be purchased since replacement of some of the fittings is probable for the next refueling outage.

Heater Drain: Three locations were examined. Erosion/corrosion was detected in the MSR shell side drains, however, no corrective action was specified, since the fittings should survive the next cycle of operation without encroaching on code minimum wall thickness.

The attached document is a database summary of inspection results and activities.

The "piping/fitting labels" correspond to those listed in the Attachment A, which is the inspection program document.

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Page No. I

'4/IO/8'j-.

SECO STEAN/MATER PIPING INSPECTIONS PIPING/ DRAMIHG SHEET HCR CONPOHEHT MIH. MALL,HONIHALCODE ACTUAL DISPOSIT!OH PREDICTED

~ 'TIH6 REFERENCE HO. (IH) MALL NIH. EROSION REPLACENEHT

. ~EL NEASURED/ (IH) 'MALL RATE OUTAGE IHSP. OUTAGE REQMT. (IH/10 4 HRS)

B-01-E-01 BLOMDOMH B 1 H/A ELBOM 0,203/1987 HOHE REIHSPECT IH REPLACENEHT HOT DETECTED 2-3 OUTAGES ANTICIPATED FOR LIFE OF PLANT B-01-E-02 BLOMDOMN B-l H/A ELBOM 0.215/1987 NOHE REIHSPECT IH REPLACENEHT HOT DETECTED 2-3 OUTAGES ANTICIPATED FOR LIFE OF PLAHT B-01-E-03 BLOMDOMH B-l H/A ELBOM 0.213/1987 HOHE REIHSPECl'H REPLACEHEHT HOT DETECTED 2-3 OUTA6ES ANTICIPATED FOR LIFE OF PLAHT B-02-E-Ol BLOMDOMH B-2 H/A ELBOM 0.228/1987 HONE REIHSPECT IH REPLACENENT HOT DETECTED 2-3 OUTA6ES ANTICIPATED FOR LIFE OF PLANT J2-E-02 BLOMDOMH B-2 H/A ELBOM 0.212/1987 NPME REIHSPECT IS REPLACENEHT HOT DETECTED 2-3 OUTA6ES AHTICIPATED FOR LIFE OF PLAHT B-94-E-01 BLOMDOMH B-42 N/A ELBOM 0.362/1987 NOHE REIHSPECT IH REPLACENENT HOT DETECTED 2-3 OUTAGES AHTICIPATED FOR LIFE OF PLAHT

~ B-94-T-01 BLOMDOMH B-42 H/A TEE 0.319/1987 HOHE REIHSPECT IH REPLACENEHT Hur DETECTED 2-3 OUTA6ES AHl'ICIPATED FOR LIFE OF PLANT ur 18 E 01 8770 G" 125 BF H 4 N/A ELBOM 1.76/1987 HOHE RETHSPECT IN REPLACEHEHT HOT DETECTED 2-3 OUTAGES ANTICIPATED FOR LIFE OF PLAHT BF-18-T-01 8770-6-125 BF-M-4 H/A TEE 1.5/1987 HOHE REIHSPECT EN REPLACEHEHT NOT DETECTED 2-3 OUTA6ES ANTICIPATED FOR LIFE OF PLANT BF-22-T-01 8770-G-125 BF-M-5 H/A TEE 1.0/1987 HOHE REINSPECT IN REPLACENEHT HOT DETECTED 2-3 OU'TA6ES ANTICIPATED FOR LIFE OF PLAHT

Page Xo. ,

2, 44/JO/87 .

SECOHD STEAN/MATER PIPIH6 IHSPECTIOHS PIPIHG/ DRA'MIH6 SHEET XCR COHPOHEHT NIH. MALL HONIHAL CODE ACTUAL DISPOSITIOH PREDICTED

~IKG REFEREHCE XO., (IH) MALL NIH. EROSIOH REPLACENEHT

."L NEASURED/ (IH) MALL RATE OUTAGE IHSP. OUTAGE REONT. (IH/10"4 HRS)

C-21-E-Ol 8770-6-125 C-E-10 H/A ELBOM HONIHAL HOHE REINSPECT IH REPLACENEHT XOT DETECTED 2-3 OUTAGES ANTICIPATED FOR LIFE OF PLANT C-42-B-OJ 8770-6-125 C-E-2 H/A BRANCH 0.525/1987 HOHE REINSPECT IH REPLACENEHT HOT DETECTED 2-3 OUTAGES AHTICIPATED FOR LIFE OF PLAHT ES-02-8-01 8770-6-125 ES-B-2 BRANCH 0.364/1987 0.422 0. 179 0.0090 27 ES-02-E-01 8770-6-J25 ES-B-2 ELBOM 0.220/1987 0.422 0.179 0.032 ES-02-E-01 8770-6-125 ES-B-2 PIPE DH 0.391/1987 0.422 0.179 0.0048 51 ELBOM 02-E-02 8770-6-125 ES-B-2 ELBOM 0.370/1987 0.422 0.179 0.0081 30 ES-02-E-02 8770-6-125 ES-B-2 PIPE UP 0.370/1987 0.422 0.179 0.0081 ELBOM ES-02-SP-01 8770-6-125 ES-B-2 PIPE 0.360/1987 0.422 0. 179 0.0096 25 ES-02-T-Ol 8770-6-125. ES-B-2 TEE 0.240/1987 0.422 0.179 0.028 ES-02A-B-01 M730JJJ71/N SH 1 STOVE 0.265/1987 .0.422 0. 100 0.024 8770-4427 PIPE ES-02A-E-Ol M730JJJ71/N SH 1 NITRED 0.215/1987 0.422 0.100 0.032 10 8770-4427 ELBOMS ES-02A;E-02 M730JJJ71/N SH 1 NITRED 0.215/1987 0.422 0.100 0.032 10 8770-4427 ELBOMS ES-03-B-OJ 8770-6-125 ES-B-l J-036 BRANCH 0.160/1987 0.422 0.198 0.044 REPLACED H/A ES-03-8-01 8770-6-125 ES-B-l J-036 ST. PIPE 0.230/1987 0.422 0. 198 0.030 REPLACED H/A ES-03-8-02 8770-6-125 ES-B-l'T. PIPE 0.285/1987 0.422 0.198 0.021

Page Ho. 3 04/10/87 '.-

SECOIIDSTEAD/RATER PTPTNR IIISPECTTOIIS PIPIH6/ 0RAMIH6 SHEET HCR CONPOHEHT NIN. MALL XONIHAL CODE ACTUAL DISPOSITION PREDICTED F 'H6 REFERENCE HO. (IH) MALL NIH. EROSIOH REPLACENEHT L.. NEASURED/ (IH) MALL RATE OUTAGE IHSP. OUTA6E REONT. (IH/10"4 NRS)

ES-03-8-03 8770-6-125 ES-B-l BRAHCH 0.285/1987 0.422 0.198 0.021 ES-03-B-03 8770-6-125 ES-B-l ST. PIPE 0.280/1987 0.422 0.198 0.022 10 F ~-E-01 8770-6-125 ES-B-l 1-036 ELBOM 0.235/1987 0.422 0.198 0.029 REPLACED H/A ES-03-E-01 8770-6-125 ES-B-l 1-036 PIPE 0.260/1987 0.422 0.198 0.025 REPLACED H/A ES-03-E-02 8770-6-125 ES-B-1 1-036 ELBOM 0.240/1987 0.422 0.198 0.028 REPLACED H/A ES-03-E-02 8770-6-125 ES-B-1 1-036 PIPE 0.310/1987 0.422 0.198 0.017 REPLACED H/A ES-03-E-03 8770-6-125 ES-B-1 1-038 ELBOM 0.210/1987 0.422 0.198 0.033 REPLACED H/A ES-03-E-03 8770-6-125 ES-B-1 1-038 PIPE 0.210/1987 0.422 0.198 0.033 REPLACED H/A ES-03-E-04 8770-6-125 ES-B-l 1-037 EL&0M 0.160/1987 0.422 0. 198 0.042 REPLACED H/A ES-03-E-04 8770-6-125 ES-B-l 1-037 PIPE 0.225/1987 0.422 0.19& 0.031 REPLACED H/A ES-03-E-05 8770-6-125 ES-B-1 1-033 ELBOM 0.190/1987 0.422 0.198 0.0362 REPLACED H/A

~3-E-05 8770-6-125, ES-B-l 1-033 PIPE DM 0.220/1987 0.422 0.198 0.0315 REPLACED H/A 4

ELBOM ES-03-E-OtD 8770-6-125 ES-B-l ELBOM 0.280/1987 0.422 0.198 0.0221 10 ES-03-E-06 8770-6-125 ES-B-1 PIPE DH 0.260/1987 0.422 0.198 0.0253 ELBOM ES-03-E-07 8770-6-125 ES-B-l 1-039 ELBOM 0.310/1987 0.422 0.198 0.0175 13

'H-E-07 8770-6-125 ES-B-l 1-039 PIPE DH 0.240/1987 0.422 0.198 0.0284 ELBOM

Page Ho...

04/10/87 "

SECOHDA STEAN/MATER PIPIH6 IXSPECTIOHS'HEET 0;

PIP IKG/ DRAMIHG HCR CONPOHEHt NIH. MALL HONINAL CODE ACTUAL DISPOSITION PREDICTED

"'~IHG REFERENCE HO. (IH) MALL NIH. REPLACENEHT EROSIOH'EASURED/

L (IH) MALL RATE OUTAGE IHSP. OUTAGE REONT. (IX/10"4 HRS)

ES-03-E-0& 8770-6-125 ES"B-1 ELBOM 0.300/1987 0.422 0.198 0.0190 12 ES-03-E-08 8770-6-125 ES-B-l PIPE DH 0.320/1987 0.422 0.198 0.0159 ELBOW

'}3-E-09 8770-6-125 ES-B-l ELBOW 0.260/1987 0.422 0.198 0.0253 ES-03-E-09 8770-6-125 ES-B-l REDUCER 0.400/1987 0.422 0. 198 0.0034 66 DH ELBOW ES-03-SP-01 8770-G-125 ES-B-l STR PIPE 0.2&0/1987 0.422 0.198 0.0221 10 ES-03-SP-02 8770-6-125 ES-B-l STR PIPE 0.290/1987 0.422 0.198 0.0206 ES-04-8-01 8770-6-125 ES-B-l 1-016 BRANCH 0.280/1987 0.500 0.198 0.0343 REPLACED H/A

'l ES-04-B-02 8770-6-125 ES-B-l BRAHCH 0.230/1987 0.422 0.198 0.300 ES-04-E-01 8770-6-125 ES-B-l 1-01& PIPE DH HOT NEASURED 0.422 0.198 REPLACED H/A .

ELBOM ES-04-E-02 8770-6-125 ES-B-l 1-016 ELBOM 0.200/1987 0.422 0.198 0.0346 REPLACED H/A ES-04-E-03 8770-6-125 ES-B-1 1-025 ELBOW 0.245/1987 0.422 0.198 0.0276 04-E-03 8770-6-125 ES-B-1 1-025 PIPE DX 0.290/1987 0.422 0.198 0.0206 ELBOM 10 ES-04-E-04 8770-6-125 ES-B-l ELBOW 0.290/1987 0.422 0.198 0.0206 ES-04-E-04 8770-6-125 ES-B-l PIPE DH 0.340/1987 0.422 0.198 0.0128 12 ELBOM ES-04-E-05 8770-6-125 ES-B-l ELBOW 0.300/1987 0.422 0.198 0.0190 12 04-E-05 8770-G-125 ES-B-l PIPE DH 0.260/1987 0.422 0.198 0.0253 ELBOM

I Page Ho. 5

'04/10/87' SECOND STEAN/MATER PIPING IHSPECTIOXS

, PIPING/ SHEET HCR COHPOHEXZ MIH. MALL XOHINAL CODE ACTUAL DISPOSIZIOH PREDICTED

.L'RAMIN6 IHG REFEREHCE HO. (IH) MALL HIH. EROSIOH REPLACEHEHZ HEASURED/ (IH) MALL RAZE OUZAGE IHSP. OUTA6E REOHT. (IN/10"4 HRS)

ES-04-E-06 8770-6-125 ES-B-l ELBOW 0.280/1987 0.422 0.198 0.0221 10 ES-04-E-06 8770-6-125 ES-B-1 PIPE DH 0.300/1987 0.422 0.198 0.0198 ELBOM i4-E-07 8770-6-125 ES-B-l 1-032 ELBOM 0.300/1987 0.422 0.198 0.0190 REPLACED H/A ES-04-E-07 8770-6-125 ES B-l 1-032 PIPE DH 0.135/1987 0.422 0. 198 0.0447 REPLACED N/A ELBOW ES-04-E-08 8770-6-125 ES-B-1 1-031 ELBOM 0.340/1987 0.422 0.198 0.0127 18 ES-04-E-08 8770-6-125 ES-B-l 1-031 PIPE DH 0.160/1987 0.422 0.198 0.0408 REPLACED H/A ELBOM ES-04-E-09 8770-6-125 ES-B-l ELBOM 0.320/1987 0.422 0.198 0.0159 14 ES-04-E-09 8770 6-125 ES-B-1 PIPE DH 0.300/1987 0.422 0.198 0.0190 12 ELBOM ES-04-E-10 8770-6-125 ES-B-l ELBOW 0.300/1987 0.422 0.198 0.0190 12 ES-04-E-10 8770-G-125 ES-B-1 PIPE DH 0.256/1987 0.422 0.198 0.0259 ELBOW ,

ES-04-E-. 11 8770-6-125 ES-B-1 ELBOW 0.300/1987 0.422 0.198 0.0190 12 04-E-11 8770-6-125 ES-B-1 PIPE DH 0.240/1987 0.422 0.198 0.0284 ELBOW ES-04-E-12 8770-6-125 ES-B-1 1-020 ELBOW 0.280/1987 0.422 0.198 0.0221 ES-04-E-12 8770-6-125 ES-B-1 1-020 PIPE DH 0.180/1987 0.422 0. 198 0.0377 REPLACED H/A ELBOW ES-04-E-13 8770-6-125 ES-B-l 1-017 ELBOW 0.340/1987 0.422 0.198 0.0128 18 E-13 8770-6-125 ES-B-l PIPE DH 0.255/1987 0.422 0.198 0.0260 ELBOM

Page Ho. 6 04/10/87"'>>

SECDRDShTEAII/MATER PTPIMM 1IISPECT!DMS '

PIPIHG/ DRAMIH6 SHEET HCR COHPOHEHT HIH. MALL HOHIHAL CODE ACTUAL DISPOSITIOH PREDICTED

'IHG REFEREHCE HO ~ (IH) MALL MIH. EROSIOH REPLACENEHT MEASURED/ (IH) MALL RATE OUTAGE IHSP. OUTA6E REQNT. (IH/10"4 HRS)

ES-04-E-14 8770-6-125 ES-B-l ELBON 0.256/1987 0.422 0.198 0.0259 ES-04-E-14 8770-6-125 ES-B-1 REDUCER 0.350/1987 0.422 0.198 0.0112 DH ELBOM "4-E-15 8770-6-125 ES-B-1 ELBOM 0.240/1987 0.422 0.198 0.0284 ES-04-SP-Ol 8770-6" 125 ES-B-1 1-040 STRAIGHT 0.170/1987 0.422 0.198 0.0393 REPLACED H/A PIPE ES-05-B-01 8770-6-125 ES-B-1 BRANCH 0.341/1987 0.422 0.100 0.0126 26 ES-05-E-01 8770-6-125 ES-B-l ELBOM 0.360/1987 0.422 0. 100 0.0096 ES-05-E-01 8770-6-125 ES-B-1 PIPE DH 0.350/1987 0.422 0.100 0.0112 29 ELBOM ES-05-SP-01 8770-6-125 ES-B-1 ST. PIPE 0.329/1987 0.422 0.100 0.0145 22 HD T-Ol 8770-6-125 HD- J-1 TEE 0.340/1987 HOHE REIHSPE'CT IH REPLACEHEHT HOT DETECTED 2-3 OUTAGES AHTICIPATED FOR LIFE OF PLAHT HD-07-T-01 8770-6-125 HD-J-2 TEE 0.400/1987 NOHE REIHSPECT IH REPLACEHEHl'OT DETECTED 2-3 OUTAGES ANTICIPATED FOR LIFE OF PLAHT H o-J-I HD-118-E-Ol 8770-6-125 ELBOM 0.200/1987 0.422 0.0346 REIHSPECT HEXT OUTA6E HD-118-E-Ol 8770-6-125 HD- J-2 PIPE DH 0.260/1987 0.422 0.0253 REIHSPECT HEXT ELBOM OUTAGE HS-05-T-01 8770-6-125 HS-L-1 TEE 3.2/1987 HOHE REIHSPECT IH REPLACEMEHT HOT DETECTED 2-3 OUTAGES AHTICIPATED FOR LIFE OF PLANT

ATTACHMENT C ST. LUCIE UNIT 2 PIPING INSPECTIONS FOR EROSION/CORROSION AUGUST 12, 1987 MCI I:5

HIGH ENERGY e

PIPING INSPECTION PROGRAM GUIDELINES TABLE OF CONTENTS SECTION DESCRIPTION PAGE (S)

BACKGROUND/PURPOSE INSPECTION SCOPE METHOD OF I NSPECT I ON IV SCREENING CRITERIA INSPECTION PROCESS VI REQUIRED DOCUMENTATION TABLE I LIST QF PIPING/FITTINGS REQUIRING INSPECTION SKETCH 1 GENERIC MAPPING AREAS ELBOWS SKETCH 2 GENERIC MAPP ING AREAS 8RANCH CONNECTIONS SKETCH GENERIC MAPPING AREAS TEES DRAWINGS:

  • MARK-UP ISOMETRIC ES-B-1 EXTRACTION STEAM PIPING ISOMETRIC MARK-UP ISOMETRIC ES-B-3 EXTRACTION STEAM PIPING ISQMETRIC MARK-UP ISOMETRIC BF-M-3 FEEDWATER PIPING ISOMETRIC MARK-UP ISOMETRIC C-E-'1 1 CONDENSATE PIPING ISOMETRIC MARK-UP ISOMETRIC C-E-15 CONDENSATE PIPING ISOMETRIC MARK-UP I SQMETR I C C-E-1 6 CONDENSATE P I P I NB ISOMETRIC MARK-UP I SOMETR IC HD-J-2 HEATER DRAIN PIPING ISOMETRIC
  • ORAHINGS ARE NOT INCLUOEO BUT ARE AVAILABLE AT FPL.

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) i HIGH ENERGY PTPING INSPECTION PROGRAM GU DELINES I. BACKGROUND/PURPOSE A RUPTURE OF AN EXTRACTION STEAM LINE ON UNIT 1 DURING CYCLE 7 RESULTED IN FORCED OUTAGE AND A LOSS OF APPROXIMATELY 39 FULL POWER HOURS. AN EXAMINATION OF THE FAILED PIPE AND A FOLLOW-UP ENGINEERING EVALUATION CONCLUDED THAT EROSION/CORROSION WAS THE FAILURE MECHANISM. EROSION/CORROSION IS AN ACCELERATED FORM OF CORROSION INDUCED BY FLOW DUE TO THE BREAKDOWN OF A PROTECTIVE OXIDE FILM FROM THE MATERIAL'S SURFACE. BECAUSE OF THE PIPE FAILURE OCCURENCE AND FOLLOW-UP ANALYSIS AND INSPECTION NEED FOR AN INSPECTION AND REPAIR PROGRAM FOR BOTH ST. LUCIE RESULTS'HE UNITS WAS DETERMINED TO EXIST.

A'LSO, IN LIGHT OF THE RECENT SURREY PLANT PIPING FAILURE INCIDENT, REPRESENTATIVE FITTINGS AND PIPING FROM SINGLE PHASE HIGH ENERGY SYSTEMS SUCH AS HEATER 'DRAIN, FEEDWATER AND CONDENSATE ARE INCLUDED. THE ADDITIONAL SINGLE PHASE LOCATIONS HAVE BEEN SELECTED IN ACCORDANCE WITH INPO SOER 87-3 GUIDANCE.

II. INSPECTION SCOPE BECAUSE OF THE SIGNIFICANT AMOUNT QF HIGH ENERGY PIPING, A METHOD FOR PRIORITIZING THE INSPECTION POINTS WAS FIRST DEVELOPED. THIS METHOD REQUIRED THE CALCULATION OF EROSION RATES FOR REPRESENTATIVE PIPING CONFIGURATIONS AND CONDITIONS. THE RATE OF EROSION/CORROSION IS A FUNCTION QF A NUMBER OF FACTORS INCLUDING:

PERCENT MOISTURE MATERIAL COMPOSITIQN pH AND WATER CHEMISTRY 1

TEMPERATURE OXYGEN FLOW PATH GEOMETRY FLOW VELOCITY BASED UPON REVIEW OF THE HIGH ENERGY PIPING SYSTEMS, THE GENERAL INSPECTION AREAS ARE AS FOLLOWS:

4A AND 4B FEEDWATER HEATER EXTRACT ION STEAM PIPING ELBOWS PLUS ASSOCIATED STRAIGHT PIPING 5A FEEDWATER HEATER EXTRACTION STEAM LINE ELBOW AND ASSOCIATED PIPING CONDENSATE PUMP FULL FLOW RECIRCULATION ELBOW AND PIPING DOWNSTREAM OF THE RECIRCULATION CONTROL VALVE

~ ~

HIGH ENERGY PIPING INSPECTION PROGRAM GUIDELINES

4. FEEDWATER PIPING AND ELBOW DOWNSTREAM OF THE FEEDWATER REGULATING VALVES
5. HEATER DRAIN TIE IN BRANCH CONNECTION TO THE CONDENSATE SYSTEM
6. MSR SHELL SIDE DRAIN ELBOW AND ASSOCIATED PIPING
7. 3B EXTRACTION STEAM LINE ELBOW AND ASSOCIATED PIPING THE SPECIFIC REQUIRED INSPECTION POINTS ARE LISTED IN TABLE I ALONG WITH A UNIQUE DESIGNATION NUMBER AND DRAWING REFERENCE. THE PLANT DRAWINGS LISTED IN THE TABLE OF CONTENTS ARE ATTACHED AND HAVE BEEN MARKED-UP TO SHOW THE SPECIFIC FITTINGS AND PIPING TO BE INSPECTED.

III. METHOD QF INSPECTION INSPECTION IS TQ BE CONDUCTED USING AN ULTRASONIC DEVICE TO MEASURE WALL THICKNESS. PIPING AND FITTINGS TO BE INSPECTED ARE TO BE MARKED OFF INTO "ZONE MAPS" AS SHOWN IN THE ATTACHED SKETCHES ~ GENERALLY s PIPING OVER 6 IN DIAMETER WILL HAVE 2 GRID SPACING, AND PIPING 6" IN DIAMETER OR LESS WILL HAVE 1" GRID SPACING.

FOR EACH INSPECTION POINT LISTED IN TABLE 1, AN "INSPECTION SCOPE" IS GIVEN. THE INSPECTION SCOPE FOR EACH GENERIC FITTING TYPE, I.E., 45 DEGREE ELBOWS, 90 DEGREE ELBOWS, TEES AND BRANCH CONNECTIONS, IS SHOWN IN DETAIL IN SKETCHES 1,2 AND <. THESE SKETCHES INDICATE HOW EACH CONFIGURATION TYPE IS GENERALLY TO BE MAPPED. THE SKETCHES ALSO INDICATE APPROXIMATELY HOW THE INSPECTION REPORT MAPS SHOULD APPEAR.

IV. SCREENING CRITERIA TABLE 1 PROVIDES A WALL THICKNESS VALUE FOR EACH FITTING OR PIPING SECTION TQ BE INSPECTED. IF INSPECTION RESULTS INDICATE THAT ALL ULTRASONIC TEST READINGS ARE EQUAL TO OR GREATER THAN THE VALUE SPECIFIED, THEN NO REPAIR OR REPLACEMENT ACTIVITIES WILL BE REQUIRED. IF ANY ULTRASONIC TEST RESULT IS LESS THAN THE VALUE SPECIFIED, THEN AN NCR IS TO BE GENERATED WHICH INCLUDES THE INSPECTION REPORT FQR THE FITTING OR PIPING SECTION AND INDICATES THE SCREENING CRITERIA VALUE VIOLATED ~

ALL INSPECTION DATA ARE TO BE TURNED OVER TO POWER PLANT ENGINEERING FOR REVIEW UPON COMPLETION.

4

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HIGH ENERGY PIPING INSPECTION PROGRAM GUIDELINES V. INSPECTION FLOW CHART THE FOLLOWING IS A DESCRIPTION OF THE GENERAL PROCESS REQUIRED FOR THE INSPECTION OF EACH FITTING OR PIPING SECTION:

ERECT SCAFFOLDING (WHERE REQUIRED)

REMOVE PIPE INSULATION AND SAVE (WHERE FEASIBLE)

OR REMOVE PAINT COATING PREPARE PIPE SURFACE FOR UT INSPECTION (WIRE BRUSH TO REMOVE SCALE AND OXIDATION)

MAP AREA TO BE INSPECTED IN ACCORDANCE WITH TABLE I AND THE APPROPRIATE SKETCH DETAIL DOCUMENT UT RESULTS:

A.'REPARE INSPECTION REPORT IF ALL UT RESULTS ARE EQUAL TO OR GREATER THAN THE SCREENING CRITERIA B. PREPARE INSPECTION REPORT AND NCR IF ANY UT RESULT IS LESS THAN THE SCREENING VALUE ENGINEERING REVIEW AND DISPOSITION NCR ( WHEN APPLICABLE)

IF REQUIRED REPAIR REPAINT)

NOTE: PC/M REQUIRED IF REPLACEMENT OF PIPING/FITTINGS INVOLVED IN REPAIR REINSTALL PIPE INSULATION (OR REMOVE SCAFFOLDING

HIGH ENERGY P PING INSPECTION PROGRAM GUIDELINES VI I. REQUIRED DOCUMENTATION AN INSPECTION REPORT SHALL BE PREPARED FOR EACH INSPECTION POINT ~

THIS INSPECTION REPORT SHALL INCLUDE, AS A MINIMUM, THE FOLLOWING INFORMATION:

i. DRAWING NUMBER
2. PIPING/FITTING LABEL (AS LISTED IN TABLE I)

SCREENING CRITERIA

4. UT MAP(S) AS INDICATED BY TABLE I AND THE APPROPRIATE SKETCH DETAIL
5. NCR'UMBER ( IF NCR REQUIRED)

TABLE I ST. L CIE UNIT 2 EROSION/CORROSION INSPECTION PROGRAM 1987 I'WhIPING/

FITTING DRAWING ZONE MAP SCREENING LABEL REFERENCE TYPE CRITERIA NOTES 2BF-13-E-01 BF-M-3 SKETCH 1 0 90" FEEDWATER REG TvPE I STATION 2C-21-E-01 C-E-16 SKETCH 1 0.330" CONDENSATE FULL FLOW

-TYPE I I REC RC 2C-35-T-01 C-E-11 SKETCH 3 0.370" 2-3A HTR TO 2-A

-TvPE III DRAIN COOLER 2C-37-B-01 C-E-15 SKETCH 2 0.385" HTR DRAIN TO

-TvPE III CONDENSATE 2ES-01-E-Ol ES-B-1 SKETCH 1 0.250" EXTRACTION STEAM TO TvPE I 2-5A HTR 2ES -0 1-E-02 'S -B-1 SKETCH 1

-TvPE I, 0.250" EXTRACTION STEAM TO 2-5A HTR 2ES-03-E-01 ES-B-3 SKETCH 1, 0.256" EXTRACTION STEAM TO

-TvPE I 2-4A 2ES-03-E-02 ES-B-3 SKETCH 1 0. 256" HTR'XTRACTION STEAM TO

-TyPE I 2-4A 2ES-03-E>>03 ES-B-3 SKETCH 1 0.256" HTR'XTRACTION STEAM TO

-TYPE I 2<<4A 2ES-04-E-01 ES-B-3 SKETCH 1 0. 256" HTR'XTRACTION STEAM TO

-TYPE II 2-4B 2ES'-06-E>>o l. ' ES-B-1 SKETCH 1 0. 10" HTR'XTRACTION STEAM TO TvPE I 2-3B HTR'B

. 2HD-118-E-Ol HD-J-2 SKETCH 1 0 150" MSR SHELL DRAIN TvPE I TO 2-4B HTR

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ATTACHMENT D ST. LUCIE UNIT 1 TURBINE CROSS UNDER PIPE INSPECTION 1983 REFUELING OUTAGE

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1.0 PURPOSE The purpose of this report is to provide Power Plant Engineerings inspection results and details of the various repairs that were performed on the St. Lucie Unit 81 turbine cross under piping during the 1983 refueling outage. Also included are recommendations for future inspections and repairs.

2.0 SCOPE The scope of this report is applicable to the following:

k 2.1 Components Inspected

a. Pipe wall

'b. Backing rings

c. Turning vanes
d. Turning vane supports
e. Expansion joints
f. Manways 2.2 Component Repairs
a. Turning vane supports
b. Manways
c. Backing rings 2.3 Recommendations
a. Future repairs
b. Periodic inspections
3. 0. SYSTEM DESCRIPTION The turbine cross under piping consists of four (4) 36 inch lines connecting the HP turbine exhaust to the four (4) moisture separator reheaters. The pipes are equipped with turning vanes at each bend to prevent pipe wall erosion. Each pipe section has .six (6) manways located between the turning vanes to allow

.,'~ for access (see the attached Fig. 1 for piping layout).

4.0 COMPONENTS INSPECTED The foll'owing manways were opened to allow for both manway repairs and internal pipe inspections: 1A1, 1A2, 1A6, 1B4, 1C2, 1C4, 1C5, 1D1, 1D2, 1D3, 1D5, and 1D6. Listed below are the results of the inspections.

4.1 Pipe Wall The cross under piping itself showed no signs of significant erosion. The findings in this inspection were very similar to those found in Ref. 7.1. The majority of the piping has a magnetite coating which has protected the pipe from erosion.

4.2 'ac g Rings All of the backing rings that vere inspected had eroded considerably. A few backing rings had been completely cut through in spots. Also, some of the backing rings had created turbulence which in turn

'caused minor downstream pipe wall erosion.

4.3 Turning Uanes All the turning vanes insp'ected showed no signs of erosion or damage. The welds attaching, the vanes to the pipe wall also appear to be in good shape.

4.4 Turning Vane Supports The turning vane supports, in all cases, have experienced significant erosion. Erosion patterns are similar to the details provided in Ref. 7.1.

4.5 Expansion Joints In most cases, the expansion joints and links did not exhibit any signs of erosion or damage. At one expansion joint (in the 1C2 portion of pipe), upstream pipe wall erosion was present in front of the upper and lower link.

This erosion pattern is detailed in Ref. 7.2.

4.6 Manways The majority of the manways that were removed were significantly damaged because they had been seal welded to eliminate steam leakage. Several manways also showed signs of warpage and steam cuts. Manway gasket materials were not consistent.

5.0 COMPONENT REPAIRS The following repairs had been performed during the 1983 outage:

5.1 Turning Vane Supports Three test repair procedures for the turning vane supports were provided within PC/M 82-82. Times required to perform each repair were documented for the sake of comparison to determine which approach was most cost effective.

The first repair consisted of complete removal of the existing supports and replacing them vith new stainless steel bars as recommended by Westinghouse. The leading edge supports between manways 1Dl and 1D2 had been replaced.

It was originally requested that Bechtel replace the trailing edge supports at this turning vane also, but Bechtel had inadvertently removed and replaced the leading edge support between manways lAl and 1A2. The total number of manhours required to repair these four (4) supports was 272 manhours.

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assumed The second J

r estimate provided via Ref. (worst case) 160 hours0.00185 days <br />0.0444 hours <br />2.645503e-4 weeks <br />6.088e-5 months <br /> to repair four (4) supports.

repair consisted of welding a stainless steel strip to only the face of the existing carbon steel support. This repair was performed.to the leading edge support of the turning vane located between manways 1D2 and 1D3. This repair to only two (2) supports took approximately 108 manhours to complete.

The third repair consisted of welding a bead of metal on the upstream, outer face of both a leading and trailing edge support. One leading edge support located between manways 1A2 and 1A3 plus one trailing edge support located between manways 1C4 and 1C5 received the weld bead repair. The other supports were left alone for the sake of comparison (see Fig. 2 for details).. The time required to repair one (1) support in this manner was 20 manhours.

Please note that the remaining supports within the cross under piping received no repairs.

I

. 52 Manways The affected manway covers were removed and shipped off site to be machined flat. No more than 1/8" of metal was to be removed from the manway covers. The manway bosses were machined on site by Bechtel.

After machining and pipe repairs had been completed, the manway covers were replaced. Flat, rubber impregnated asbestos gaskets were utilized and the bolts torqued to 240 ft. lbs. The entire portion of the cross under piping is now accessible by the presence of bolted manways.

5.3 Backing Rings

/

Because of the findings while inspecting the backing rings, it was recommended that all accessible backing rings be removed and the pipe wall repaired as necessary using the details provided in PC/M 82-82. This recommendation is also in accordance with Ref. 7.2. Zn most cases, backing ring removal was relatively easy and the follow"up pipe repair not significant.

6.0 RECOMMENDATIONS 6.1 Future Repairs

a. Power Plant Engineering recommends that the remaining backing rings be removed and the pipe wall restored when the remaining portions of pipe are made accessible.

This should be done within the next 3 - 4 years to help minimize the amount of pipe wall erosion caused by the backing rings.

b. The turning vane support repairs should be inspected within the next 3 years. Engineering would then assist the plant in determining which of the test repair(s) should be P ower utilized based on cost and support p lif Plant Engineering, based on discussions with e.

Westinghouse has established that the supports are necessary to maintain turning vane integrity. As portions of the cross under piping become accessible, turning vane support repairs should take place as deemed necessary by inspections.

c. Expansion joints should also be periodically inspected to determine the necessity of repairs. Ref. 7.2 provides the details to repair the pipe wall.

6.2 Periodic Inspections Power Plant Engineering recommends that the turning vane support repairs performed during the 1983 refueling outag b innspected within the next 3 years. This can be done by removing manways lAl or 1D1, 1D2, 1A2 and 1C5.

The remaining manways should be removed within the next 3 " 4 years for backing ring removal. This includes the 1A3, lA4, lA5, 1B1, 1B2, 1B3, 1B5, 1B6, 1'Cl, lC3, lC6 and 1D4 manways. Turning vane support repairs should be performed within this portion of pipe where necessary using the methods selected. These repairs should be documented because of the unlikelyhood that these sections will need to be inspected in the immediate future.

Power Plant Engineering does not feel that compliance with Westinghouse's recommendation of inspecting the cross under piping during all refueling outages (see Ref. 7.2) is necessary.

Following the next piping inspection, Po~er Plant Engineering will aid in outlining a continuous inspection procedure taking into consideration all of the repairs that have been performed.

7.0 REFERENCES

7.1 Ebasco letter S1 "BF-82-117, "Turbine Cross Under Pipe Inspection", dated March 31, 1982.

7.2 Westinghouse letter,. W.F. Caperton to W.B. Derrickson, dated May 16, 1983.

7.3 IOC, C.S. Kent to D.K. James, dated August 25, 1982.

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