ML20086F660
| ML20086F660 | |
| Person / Time | |
|---|---|
| Site: | Robinson  |
| Issue date: | 06/13/1975 |
| From: | Utley E CAROLINA POWER & LIGHT CO. |
| To: | Moseley N NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| Shared Package | |
| ML20086F657 | List: |
| References | |
| NG-75-885, NUDOCS 8401030452 | |
| Download: ML20086F660 (24) | |
Text
{{#Wiki_filter:I n* f) (\ E' C9&L Carolina Power & Light Company June 13, 1975 FILE: NG-3513 (R) SERIAL: NG-75-885 Mr. Norman C. Moseley, Director U. S. Nuclear Regulatory Commission Region II, Suite 818 230 Peachtree Street, N.W. g -[ / Atlanta, Georgia 30303
Dear Mr. Moseley:
H. B. ROBINSON UNIT No. 2 LICENSE NO. DPR-23 INSULATION AND PIPING AFFECTED BY FAILURE OF "C" REACTOR COOLANT PUMP SEAL, "AY 2, 197.% This report is in response to the request by NRC to provide justification for not replacing wetted insula 1Elon that resulted from "C" Reactor Coolant Pump Seal failure on May 2, 1973. The discussion addresses the stainless steel insulated lines outside of "C" Reactor Coolant Pump bay, "C" Pump bay piping, and Reactor Vessel incore detector thimble penetrations. As a result of the containment flooding, piping near the contain-nent base mat was submerged. The stainless steel piping which was submerged consisted of seal water injection to RCP "A", excess letdown lines, normal letdown lines, residual heat removal line to "A" loop, and safety injection line to "A" loop cold leg. Refer to attached Table 1. This constitutes approximately 650 feet of piping. Portions of this piping were flooded fron early Friday norning, May 2, 1975 to about 0400 Sunday morning, May 4, 1975. The chloride concentration of the water was 0.25 ppm as measured on "ay 2, 1975. Therefore, there was a concern for the saturation of the insulation with chlorides, possible leaching out on piping, and the potential for chloride stress corrosion. Westinghouse was contacted to provide recom-nendations for corrective action. The initial Westinghouse reply was received on May 6, 1975. Recommendations were to remove insulation from all submerged stainless steel piping and all wetted piping in the area of the spill, clean the pipe, and reinsulate. It was also suggested to remove insulation from the bottom of the reactor vessel and to rinse the vessel and clean the incore thinble penctrations. The specification which was referenced for use in the evaluation was Westinghouse PS 84351 NL, Revision 2
" Determination of Surface Chlorides and Fluoride Contanination on Stain-less Steel Material." This specification allows a raxinum chloride con-centration of 0.0015 ng/dm 2 for insulated surfaces.
8401030452 751001 PDR ADOCK 05000261 S PDR 336 Fayetteville Street . P. O. Box 1551. Raioigh, N. C 27602 s' (
- Oa pa Mr. Norman C. !!oseley June 13, 1975 Initial plans were then made to remove all the insulation and proceed as suggested. However, a sampling program was begun on loop piping that was not wetted by the incident, and the chlorides on this piping were found to be higher than the referenced acceptance limits. Refer to Table
- 3. Based on this as-found condition and a concern for nininizing radiation exposures of workers required to remove insulation and reinsulate the sub-nerged piping Westinghouse was again contacted to provide clarification and/or justification for the proposed acceptance criteria. It was at that time that Westinghouse recommended sampling the piping and piping insulation with respect to the acceptance criteria in Westinghouse PS 83336 KA,
" Requirements for Thernal Insulation Used on Austenitic Stali.less Steel Reactor Plant Piping and Equipment." To provide data on the worst case, insulation was removed from each pipe at its lowest elevation, and the sample results indicated that the insulation and piping were acceptable.
Refer to attached Table 2. Westinghouse was then requested to provide a justification for the applicability of the process specification for insulation to the piping. A report was received on May 21, 1975 j us ti-fying the acceptance standards. Refer to Attachment 1. This report concluded that the data falling within the acceptance curve of the subject specification indicated that sufficient mmounts of sodium silicate were present in the insulation to prevent chloride stress corrosion. Further there is no concern for the contamination if the surface is covered with sodium silicate inhibited insulating material when it is ascertained that there is sufficient silicate inhibitor to prevent halide stress cracking. This mechanisn for inhibition of halide stress corrosion was established by H. P. Karnes in his report, "The Corrosive Potential of Wetted Thernal Insulation," presented at the AICHE 57th National Meeting, September 26-29, 1965. With this final justification it was decided that the wetted piping and insulation were acceptable without replacement. A plot of the chemical analysis data for each line and its corresponding insulation is enclosed as Graph 1. This acceptance curve is per the subject Westinghouse Specification PS 83336 KA which corre-sponds to Figure 1 of Regulatory Guide 1.36, "Non-yetallic Thermal Insula-tion for Austenitic Stainless Steel". This indicates that sufficient leachable sodium and silicate ions are precent w. assist in minimizing the effects of the chloride and fluoride To account for all chlorides present, the plot. consists of sodium and silicate ions versus chloride and fluoride ions in the insulation plus chloride and fluoride ions on the pipc. On this basis, even though the lines were in contact with the contaminated water for sone time, no adverse chemical effects attributed to halogens and stress corrosion have resulted. i
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; ': O O Mr. Norman C. Moseley June 13, 1975 Also, as pointed out in Westinghouse letter CPS-75-078 (Attach-ment 2) pipe surface contamination en and all pipes that were submerged does not exceed 0.0015 mg/dm2 which is the specification to be met for cleaning pipe prior to insulation installation. Westinghouse further states that it is believed that chloride contamination observed on the submerged piping is not potentially hazardous with respect to chloride stress corrosion and continued operation is justified without any other innediate action.
So that the sections of pipe that were submerged can-be better visualized, Line Diagrams 1 through 7 are provided to show these pipe loca-tions and elevations. The diagrams also show that all of these lines in-clude at least one isolation valve between the reactor coolant loop piping and the section of submerged pipe. Thus,-in the event that a problem might inconceivably occur with pipe cracking and leakage, the line can be isolated. The piping systems within "C" Reactor Coolant Pump Bay experienced significant wetting of the insulation due to spray from the failed pump seal, but none were submerged due to water accumulation on the containment floor. The inlet and outlet "C" loop piping, "C" Reactor Coolant Pump casing, and "C" loop insulation were examined for possible chloride and fluoride ion problens. Also in order that a comparison between dry and wetted nain coolant piping insulation could be made, samples were also analyzed fron "A" and "B" main coolant loops. These results are given in Table 3 and are.niotted on Graph 2. The same basis for acceptance of this insulation as was used above was applied in this case. Incore thimble penetrations at the base of the Reactor Vessel are not insulated, but they were submerged during the accident. In order to insure that no problem existed, all thimble penetrations on the vessel base were thoroughly cleaned, and three nonadjacent penetrations were sampled for chloride and fluoride contamination. These results are also given in Table 3 and show that there is no indication of chloride and fluoride ions being present. The following lists the specific recommendations made by Westing- !, house in their initial letter of May 6, 1975 and a summary of the corrective i action taken:
- 1. Insure vessel safe ends were not contaminated with l chlorides.
Corrective Action: The vessel safe ends did not get wet due to.being at a higher elevation than the water level.
+
o O ov , Mr. Nornan C. Moseley June 13, 1975 4 2. Insure all instrumentation tubing at the base of the vessel is clean. Corrective Action: All incore thimble penetrations were cleaned and checked for chlorides (Table 3).
- 3. All submerged stainless steel pipe should have the insulation removed, the pipe cleaned, and the insu-lation restored.
Corrective Action: A chemical analysis was performed on each pipe and insulation at its lowest elevation (Table 2) and plotted (Graph 1). Acceptance was based on the criteria and justification received in Westing-house correspondence of May 21, 1975.
- 4. Insure that no main loop piping was submerged.
Corrective Action: No main loop piping was submerged.
; 5. All insulation in "C" Pump Bay that was wetted should be removed, the pipe cleaned, and the insulation re-placed.
Corrective Action: A chemical analysis was made of insulation in "C" Bay and compared with insulation for the other pump bays that had not been. wetted , (Table 3 and Graph 2). Acceptance was based on the same criteria as referenced in Item 3 above.
- 6. Inspect and clean bolts on the reactor coolant pumps that were contaminated by the water.
Corrective Action: The pump was disassembled and inspected and all bolts were cleaned prior to re-assembly. Based on this evaluation and corrective action it was not deemed necessary to remove and replace the wetted insulation. There is sufficient i evidence to assure that halogen stress corrosion will not occur'and the existing conditions pose no threat to plant safety. I
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- O O Mr. Norman C. Moseley June 13, 1975 As per Westinghouse recommendation a program shall be established for further piping and insulation sampling at the next scheduled outage.
This precautionary step shall be taken to confirm the results of the initial sampling and provide assurance of pipe integrity. uly ,ours, f 46%g,, E. E. Utley Vice President Bulk Power Supply DBW:cpw Attachments CC: Mr. N. B. Bessac Mr. T. E. Bowman Mr. P. W. Houe Mr. R. E. Jonec Mr. J. B. McGirt Mr. D. B. Waters c i %_ . , - , - w. ,# _- i
ATTATCE'T 1 g y o oU
. Westinghouse Electric Corporation Power Systems Pwasystemsoivisim q
mm Co. PittsburghPensylvania15230 May 21, 1975 ST-CO-668
. Mr. J. B. McGirt, Plant Manager Carolina Power & Light Company -
P. O. Box 790 llartsville, South Carolina 29550
Dear Mr. McGirt:
Surface Chloride Concentrations on CPL Loon Pitsing
~
This is in response to your request for an explanation of the rationale cmployed in writing the Westinghouse Cbcaistry Specification Number 1.8 - for surf ace chloride and fluoride contamination on stainless steel mat-crials and its relatienship to recently determined chloride surface con-tamination on CPL loop piping. That specification is included in WCAP-7452, Revision 1, " Chemistry Criteria and Specifications for Westinghouse Pressurized Water Reactors". Testing at Westinghouse laboratories has shown that stressed austenitgc stainicss steel sampics exposed to less than the specified 1.5 ug/dn chloride or fluoride surf ace contamination did not experience stress cracking. It is recognized that higher values of surf ace halide contamination can be tolerated without the material be-ing corrosively attacked when the stainless is covered with unjacketed thermal insulation containing low values of leachabic halides as well as a concentration of leachabic silicates sufficiently great to provide in-hibition to external stress corrosica cracking./l llowever, in the pro-cess of installing insulation on piping and equipment, it is possibic that small areas may be 1cft uncovered and thus might not receive the ' benefits of the silicate inhibitor. It is specified, therefore, that all stain 1 css surfaces be c1 caned to the low surface halide level of 1.5 pg/dm2 before application of thermal insulation. This specification is intended to be applied immediately prior to the time that surfaces are to have insulation installed either prior to plant startup or during post op"crational maintenance when it becomes necessary to reinstall sections of insulation.
. If ynjacketed, asbestos-type insulation containing a given concentration of leachabic halides and leachable silicates is removed from a stainicss surface and the surface is then smear-sampled for contamination, it is ex-pected that some level of contamination will be determined in excess of
._. the specified limit for surface halides. Such contamination would result -
, from particles of the insulating material remaining on the stainicss sur- )
face after the bulk of the insulation had been removed. In the situation
/1 II. F. Karnes, The Corrosive Potential of Wetted Thermal Insulation, presented at the AICllE 57th National Meetinti, September 26 - 29, 1965; Conf. 650905-2.
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\"# ST-CO-668 CPS-75-071 Page 2 described, the contamination would not be of concern if the surface is to be covered with sodium silicate inhibited insulating material when it is ascertained that there is sufficient silicate inhibitor available to pre-vent halide stress cracking caused by sources of halides leached from the insulation or already present on the stainless surface. In order for a cracking mechanism to be initiated, the halide surface contamination must be wetted such that the halides become ionic in form. For that situation to occur, water must enter the insulation system before it can contact the dry halide contamination which is passive in the dried state. The sodium silicate inhibitor would then be leached by the water from the insulation, along with any leachabic halides and then would be deposited on the heated stait.less steel surface where the silicates would prevent the halides from causing cracking. This mechanism of inhibition of halide stress corrosion cracking by the presence of sodium silicate inhibitors in thermal insulat-ing materials was established by Karnes in the previously referenced report of testing completed at Knolls Atomic Power Laboratory.
A review of the surface halide data recently collected from CPL loop piping and reactor coolant puup housing, along with data gleaned from analyses of sampics of insulation removed from CPL loop piping, supports the contention , that sufficient silicate inhibitors are available on the insulated stainless surfaces to preclude halide stress cracking. These data are presented below: Table 1 . Cl- F- Cl- F- SiO 2 Na Sample Location (en/dn2 ) (mc/dm2 ) ppm ppm ppm ppm C Loop Inlet 0.0037 N/D C Loop Outlet 0.061 N/D C RCP Location #1 0.050 N/D C RCP Location #2 0.047 N/D' A Loop Insulation 3.5 N/D 437 787 B Loop Insulation 3.75 N/D 900 1500 C Loop Insulation 3.25 N/D 375 275' N/D Not Detectable The acceptability of thermal insulation is judged by establishing the ratio of the Icachabic sodium + silicate concentrations to the leachable chloride + fluoride concentrations. This ratio of acceptability is easily determined l by comparison of the data with a plot provided in the Westinghouse Process Specification 83336 KA, Requirements for Thermal Insulation Used On Austenitic Stainless Steel Reactor Plant Piping and Equipment. The loop insulation data verifies the fact that the insulation is acceptable for use in the subject application and will provide the necessary inhibition to halide stress corro-sion cracking. In conclusion, it may be stated that the chloride contamination observed on CPL loop piping and C-RCP housing is not considered potentially hazardous with respect to chloride stress corrosion cracking since sodium silicate in-hibitors are available in the thermal insulation to prevent the occurrence of such a mechanism. . b
'P ,
a
O O I ST-CO-668
~
CPS-75-071 i Page 3
\
l If other questions arise concerning this subject, I would be pleased to i discuss them further. Very truly yours, WESTI'NGHOUSE ELECTRIC CORPORATION i J W. Kormuth, Engineer Systems Chemistry Operations Ph'RSD Systems Technology
/ [ ;; ;_
- APPROVED: T. E. Bowman, Lead Engineer Field Operations - Southern Region JWK:TEB:als cc: N. B. Bessac '
J. F. Halifax B. J. Furr O e 1 e 4 3 .
.. ', n n :%$5;#. t- ). J -
L) O rec;,;EJ Westinghouse Electric Corporation Power Systems musaviceoir crep 45 78 Ber355 d Lo,
- Partsbt;rciPenralvna 15233 June 3, 1975
. CPS-75-078 Mr. 11. B. Bessac, Manager .Ref: (1) CPS-75-054 of fluclear Generation
- May 6, 1975 Carolina Power and Light Company P. O. Box 1551 '
(2) CPS-75-071of P,aleigh, f; orth Carolina 27602 May 21, 1975
Dear Mr. Bessac:
Subject:
Analysis of Submerged Stainless Piping and Potential for Halide Stress Corrosion Cracking at H. B. Robinson Unit t!o. 2 On Tuesday, Pay 27, 1975 in a telephone conversation, we discussed the potential problems that might occur beccuse the H. B. Robinson Unit f:o. 2 had been started up on May 26, 1975 without having removed the insulation from that stainless steel cioing which had been submerged and wetted during the incident of May 1,1975. This latter action had been recome. ended in paragraph 2a. of reference (1). At that time you tequested that Udsting- . I house investigate the situation to determine what would be the best action to take under the present circumstances. Since that time we have considered the matter at length and have repcrted periodically by telephone to you on tha matter. Information was provided by telephone from the plant on May 25, 1975. This information is displayed in Table I. Consultation with PWR Systems Division-Systerr.s Operations, Chemistry Operations and I;uclear Safety results in the following recontenda-tions, which are based upon Table I data being representative and accurate. Reference (2) discussed in detail the relationships between the surface level halide contamination of stainless steel piping, and the sodium silicate
~.
inhibitors present in the insulation material. A review of the data in Table II for the submerged piping continues to support the contention, as outlined in reference (2), that sufficient silicate inhibitors are available in the insulated stainless oiping to preclude halide stress cracking. Please note that all ooints asscciated with the insulation display an acceptable ratio of the leachable sodium plus silicate concentration to the leachable chloride clus fluoride concentration if plotted on Figure 2 of PS 83336 VA of 5/12/71 (Requirements for Thermal' Insulation Used in Austenitic Stainless < Steel Reactor Plant Piping and Equipment). l l - j . j . s 1
, g
Mr. N. B. Bessac' O - O CPS-75-078 Furthercore, it should be noted that no surface halide contamination exceeded . 0.0015 r.g/d=2, which is the s'occification to be met when cleaning stainless piping prior to installation of insulations. PS 84351, Rev. 2 of 12/12/72 (Determination of Surface Chloride and Fluoride Contamination on Stainless Steel). In conclusion therefore, Westinghouse believes that chloride contamination observed on the submerced piping is not considered potentially hazardous with respect to chloride stress corrosion cracking since insulstion inhibitors are still available in sufficient quantities to prevent the occurrence of the mechanism. Continued oceration of the plant is therefore, in our opinion, justified without any other immedihte action. We recor. mend that at the first available opportunity a piping and insulation sampling programs be initiated for the effected piping to confirm the represen-tative nature of the sarple: displayed in Table I.
, Please contact ce if you have any further questions on this subject.
Very truly yours,
& kn=_: =
'T. E. Bowman, Lead Engineer .
Operating Plants Services 1 cc: J. B. McGirt . J. F. Halifax _ ,a* S e O r,
TABLE I PLANT SUPPLIED DATA . PIPE IDENTIFICATION _ LENGTH WETTED (APPROX.) PIPING SWIPE RESULTS (ppm)l_ INSULATION SAMPLE RESULTS (ppm)2 C1 F1 Na SiO Cl F1 Na SiO 2 2 ,Idi-
- a. 3/4 - CH - 118 6 ft. 0.01 0 ND 1.0 0.50 0.085 ND 150 13.50 I!h0
- b. 3/4 - CH - HC ,
6 ft. 0.3D ND 2.0 0.90 0.060 ND 65 26.25 9.4
- c. 8 - SI - 37 50 ft. 0.06 ND 9.0 0.95 0.110 ND 500 41.25 10.1
~
- d. 2 - SI - 63 50 ft. 0.10 ND 2.5 2.70 '
O.110- ND 98 45.00 9.4
- e. 3/,4 - CH - ll A 170 ft. 0.035 ND 0.5 0.03 0.110 0.01 0 400 90.00 10.3
- f. 2 - CH - 20 85 ft. 0.035 ND 1.5 0.02 0.075 ND 75 33.00 9.4
- g. 2 - CH - 8C 50 ft. 0.06 ND 8.5 0.02 0.090 0.01 5 1500 120.00 10.3 h, 2 - CH - 17 220 ft. 0.02 ND 3.0 0.06 0.035 ND 100 33.00 9.6 lll .
I NOTES: (1) Swipe results ppm refer to ppm of sample liquid (mg material /l solution) (2) Insulation sample ppm refer to ppm of sample liquid (mg material /l solution) (3) ND ,= Not Detectable
/
9
7 TABLE II CONVERTEDPLAtlTDATd PIPE IDENTIFICATION PIPING SWIPE RESULTS (mg/dm2 ) 1 INSULATION SAMPLE RESULTS (pom)2 of INSULATION
- Cl F1 ila SiO Cl F1 Na SiO 2_ 2
- a. 3/4 - CH - 11B 0.0003 ND 0.0250 0.0125 '2.13 ND 3750 338 b, 3/4 - CH - 11C 0.0008 fl0 0.0500 0.0225 1.50 ND 1625 656
- c. 8 - SI - 37 ' O.0015 ND 0.2250 0.0238 2.75 ND 12,500 1031 .
- d. 2 - SI - 63 0.0003 ND. 0.0625 0.0675 2.75 ND 2450 1125
- e. 3/4 - CH - 11A 0.0009 ND 0.0125 0.0008 2.75 0.25 10,000 2250
- f. 2 - CH - 20 ,
0.0009 ND 0.0375 0.0005 'l.88 ND 1875 825
- g. 2 - CH - 8C 0.0015 ND 0.2125 0.0005 2.25 0.38 12,500 3000 h, 2 . CH - 17 0.0005 ND 0.0750 0.0015 0.88 ND 2500 825 h.
NOTES: (1) Based.upon PS84351 Rev.1 conversion; 500 mi sample solution and 20 dm 2 area: VT _ 0.5 l_ = 0.025 1 (multiplication factor) X- 20 dmd dm2 (E) Based upon PS03336 KA Conversion; 500 ml sample solution and 20 g. insulation sample: 0.5 1 = 251 (multiplication factor)
.02 kg kg
/
o 4 e
s ("\ ') G v TABLE 1 Line fiumber Descriotion 2-CH-80 Seal water injection to "A" pump 3/4-CH-11A Inlet to excess letdown heat exchanger 3/4-CH-11B Outlet from excess letdown heat exchanger 3/4-CH-11C Outlet from excess letdown heat exchanger 2-CH-17 Ilomal letdown to regenerative heat exchanger 2-CH-20 llormal letdown from regenerative heat exchanger 8-SI-37 RHR loop to "A" loop cold leg 2-SI-63 Baron injection to loop 1 cold leg l l l l m.
r
. TABLE 2 6
Chemical Analysis (PPM) Pipe Line Number Chloride Fluoride Silica Sodium 2-CH-8C 0.060 ND 0.02 8.5 3/4-CH-11A 0.035 ND 0.03 0.5 3/4-CH-11B 0.010 ND 0.50 1.0 3/4-CH-11C 0.030 10 0.90 2.0 2-CH-17 0.020 ND 0.06 30 l 2-CH-20 0.035 ND 0.02 1.5 8-SI-37 0.060 ND 0.95 90 2-SI-63 0.010 UD 2.7 25 Inculation Lino Number Chloride Fluoride Silica Sodium pH 2 -CH-SC 0.90 0.015 120.00 1500 10.3 3/4-CH-11A 0.11 0.01 90.00 400 10.3 3/4-CH-11B 0.035 ND 13.5 150 9.0 3/4-CH-11C 0.06 ND 26.25 65 94 2-CH-17 0.035 ND 33.0 100 9.6 2-C H-20 0.075 ND 33 0 75 94 S-SI 37 0.11 ND 41.25 500 10.1 2-SI-63 0.11 ND 45.00 93 94 ND - Not detectable Multiplication factors noted in Table II of Attachment 2 are not included in this data.
I O O TABLE'3 - Chemical Analysis (PPM) Descrintion Chloride Fluoride Silica Sodium A loop inculation 3.5 ND 437 787 B loop insulation 3.75 ND 900 1500 C loop insulation 3.25 ND 375 275 Reactor Vessel Incore Thimble Penetratienc 1 ND ND O.125 ND 2 ND ND ND 0.04 3 ND ND O'.1 0.01 Sample Location Chloride (ur/dm ) Fluoride (ur/dm ) C Loop Inlet 3.7 ND C Loop Outlet 61 ND 0 RCP Lccation #1 50 ND C RCP Location #2 47 ND
.ND - Hot detectable \
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