ML20151M448
| ML20151M448 | |
| Person / Time | |
|---|---|
| Site: | Browns Ferry  |
| Issue date: | 08/01/1988 |
| From: | Gridley R TENNESSEE VALLEY AUTHORITY |
| To: | NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM) |
| References | |
| GL-88-01, GL-88-1, NUDOCS 8808050170 | |
| Download: ML20151M448 (26) | |
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TENNESSEE VALLEY AUTHORITY CH ATTANOOGA. TENNESSEE 374of SN 157B Lookout Place AUG 011988 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555 Centlemen:
In the Matter of ) Docket Nos. 50-259 Tennessee Valley Authority ) 50-260 50-296
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BROWNS FERRY NUCLEAR PLANT (BFN) - RESPONSE TO GCLLETi;; 88-01, NRC POSITION ON ICSCC IN BWR AUSTENITIC STAINLESS STEEL PIPING, DATED JANUARY 25, 1988 The purpose of this letter is to submit BFN's responso to Bulletin 88-01 requesting informat.lon concerning Intergranular Stress Corrosion Cracking (IGSCC).
This response includos:
(1) BFN's plans regarding long-term mitigation of ICSCC, (2) inservico inspection program plans, (3) intended change to the BFN Technical Specifications, (formal submittal before restart of BFN Unit 2)
(4) confirmation of Icakago detection plans, and (5) plans for reporting to NRC of any flaws identified by this program.
The contents of this responso has been presented to the NRC staff during a meeting which took place on May 11, 1988 in the NRC offices and documented in Mr. G. Cears notes dated June 2, 1988.
During the meeting, the indications found on a specific wold (DSRHR-2-5A) were discussed. These indications have been dolormined to be the result of a lack of fusion and not ICSCC. Since this is a different subject, additional information concerning this weld will be discussed in a forthcoming letter from TVA addressing the questions raised by the staff.
Please refer any questions regarding this matter to Patrick Carler at (205) 729-2689.
Very truly yours, TENNESSEE V I.Y AUTHORITY e
8808050170 seosog R. Wy, M eh PD Nucl ar Licen ing and M ADOCK 05000259 PDC Regulatory Affairs Enclosures cc: See page 2 I
- ()bO I I An Equal Opportunity Employer
i U.S. Muclear Regulatory Commlsolon M601M8 i
ec (Enclosuros):
Ms. S. C. Black, Assistant Director for Projects TVA Projects Division U.S. Nuclear Regulatory Commission One Whito Flint, North-11555 Rockvillo Pike Rockville, Ms.ryland 20852 Mr. F. R. McCoy, Assistant Director for Inspection Programs TVA Projects Division U.S. Nuclear Regulatory Commission 9egion 11 101 Mariotta Street NW, Suito 2900 Atlanta, Georgia 30323 Browns Ferry Resident inspector Browns Ferry Nuclear Plant Route 12, Box 637 Athens, Alabama 35611 f
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RESPON3E TO GENERIC LETTER 88-01:-
REPORT OF INSPECTION, REPAIR, AND MITIGATION PLANS FOR BROWNS FERRY UNITS 1, 2, AND 3 IGSCC SUSCEPTIBLE PIPING Introduction
-The problem of intergranular stress corrosion cracking (IGSCC) has been
. addressed for each of the three Browns. Ferry Nuclear Plant-(BFN) units in a manner appropriate to the condition of each individual unit and in accordance with the requirements of the regulatory document governing IGSCC-related activities at the tine the activities were undertaken. -The most recent IGSCC
-inspections and corrective actions performed on units 2 and 3 were planned in anticipation of the release of NUREG-0313, R. 2, "Technical Report on Material Selection and Processing Guidelines for Soiling Water Reactor (BWR) Coolant Pressure Boundary Piping." Thit report of the BFN inspection, repair, and ;
mitigation plans is in response to Generic Letter 88-01, "NRC Position on IGSCC in BWR Austenitic Stainless Steel Piping," (GL 88-01) through which NUREG-0313, R. 2, was released and distributed. As requested, a response has ,
been provided for each of the five specific items listed in the generic letter.
1.0 PLANS REGARDING LONG-TERM MITIGATION OF IGSCC The measures to be taken on the BFN. units to mitigate IGSCC and to provide .
assurance of continued long-term piping integrity and reliability depend'on
- the condition of the individual unit. The mitigation plana for each unit have been prepared in accordance with the NRC positions as stated in GL 88-01. In the case of unit 2, most of the planned IGSCC mitigation measures have been implemented. The mitigation status and activities planned for future implementation are described in Section 1.3.3 below. Regarding units 1, and 3, however, final decisions have not or can not yet be made on the implementation of additional IGSCC mitigation measures. For these units, the mitigation status is given, but a schedule of planned activities will be submitted at s later date through supplements to this response.
1.1.0 Scoce of IGSCC Susceptible Piping The following wrought austenitic stainless steel piping systems and components are considered susceptible to IGSCC according to the guidelines given in GL 88-01:
- Elastor Recirculation from the recirculation inlet and outlet nozzles to l-
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the connections with residual heat removal
- Residual Heat Removal (RHR) from the recirculation system to the first isolation valve outside of the drywell penetration
- Reactor Water Cleanup (RWCU) from its connection to the RHR system to first isolation valve outside of the drywell penetration
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- Core Sorav from the core spray inlet nozzles to the drywell penetration, including the core spray inlet safe ends. The piping within and upstream of the penetration is not considered susceptible due to the lov operating temperature, generally 130' F or less. On units 2 and 3, the piping from FCV's 75-54 and 75-26 to the inlet safe ends has been replaced with carbon steel; therefore, only the welds connecting stainless fittings to the carbon steel piping are included in the scope of susceptability in these sections of piping.
- Recirculation Inlet Safe Ends
- Jet Pumo Instrumentation Safe Ends The head spray systems are not included, because they have been removed from unita 2 and 3 and will be removed from unit 1 before plant startup.
Similarly, the control rod drive return and recirculation discharge valve bypass piping have been removed from all three units and so are not considered !
here. l A review of all stainless steel piping systems was conducted in order to investigate the possibility of IGSCC susceptability in balance-of-plant systems. No such systems were found to meet the susceptability criteria as stated in GL 88-01. Therefore, no common systems at BFN are subject to the GL 88-01 requirements. The mitigation and inspection plans can therefore be developed independently for each unit, and the startup of one unit should have no impact on the inspection a..d mitigation status of the other units.
Inconel veld butter was not used in the construction of the BFN piping systems or piping to vessel connections. It is therefore not considered in this report.
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1.2.0 Unit 1 -
1.2.1 Summary of Insoections The IGSCC susceptible piping veldments of unit 1 were inspected in accordance with the requirements of IE Bulletin 83-02 in 1983. Additionally, I.T June 1986, 25 percent of the unit 1 recirculation and RHR system velds were reinspected.
1.2.2 Summary of Mitigation and Reoair Activities A detailed technical description of the inspections, repairs, and mitigction measures implemented on the unit 1 piping systems was submitted to Mr. Harold R. Denton, Director of the Office of Nuclear Reactor Regulation, on November 17, 1983, docket number 50-259. The mitigation and repair status of the unit i velds is sunmarized below.
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NUREG-0313 Inspection PIPING WELDS Number Category Cracked welds with overlays . . . .. . . . 42 . . . . . . . E or F*
Cracked welds with no mitigation . . . . . 4 . . . . . . .. .F Inspected, nonresistant welds . . . . . . .118 . . . . . . . . .D Uninspected, nonresistant velds . . . . . 19 . . . . . . .. .G TOTAL . . . . . . . . .. . . . . . . . . .183
- A review of the overlay design process to ensure compliance of the overlays with NUREG-0313, R.2, requirements has yet to be performed.
RECIRCULATION INLET SAFE ENDS Cracked components with no mitigation . . . .5 . . . . . . .. .F Uninspected, nonresistant components . . . 5. . . . . . . . .G TOTAL . . . . . . . . . . ... . .. . . 10 JET PUMP INSTRUMENTATION SAFE ENDS
! Inspected, nonresistant velds . . . . . . 10 . . . . . . .. .D 1.2.s Plans for Future Mitication and Repairs l
l Plans for additional mitigation and repair measures have not yet been finalized for this unit; however, two plans of action are under consideration. One option is full replacement of the piping, safe ends, and l penetrations with resistant material. If this option is chosen, stress improvement (SI) vill be applied to all new veldments at the time of construction, and hydrogen water chemistry will be implemented shortly thereafter. The alternative plan of action consists of the mitigations
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_4 necessary to provide increased resistance to IGSCC and improve safety and reliability without a large scale replacement. This would include: stress improvement of all non-overlaid velds; upgrading of all inadequate overlays to overlays acceptable to the NUREG requirements; the application of_ corrosion resistant cladding or local leak detection to or the remov21 of inaccessible welds; repair or replacement of the flawed recirculation inlet safe ends; and the implementation of hydrogen water chemistry. Engineering and economic-analyses will be performed to determine which course of action will both return the unit to safe, reliable operation and satisfy BFN's long range planning and budgetary needs.
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- 1.3.0 Unit 2 .
1.3.1 Summary of Inscections In 1985, the unit 2 IGSCC susceptible piping veldments were inspected in accordance with the requirements of Generic Letter 84-11. Additionally, post-induction heating stress improvement (IHSI) inspections were performed on 25 percent of the 149 welds treated between December 1984 and March 1985. The discovery of a cracked weld in the RWCU piping welds was made in 1986.
Following a second IHSI effort in 1987, 100 percent of the welds treated during the second effort were inspected. Finally, the new welds revulting from the replacement of the recirculation inlet safe ends and riser piping were all given baseline volumetric examinations in accordance with the requirements of ASME Section XI.
1.3.2. Summary of Mitization and Repair Activities A detailed technical description of the inspection, repairs, and mitigation measures implemented on the unit 2 piping system welds was submitted to NRC on December 31, 1987, in response to Generic Letter 84-11. Table 1 gives the mitigation and repair status of the unit 2 welds according to GL 88-01. This table includes 6 welds which were inadvertently omitted from the table given in Appendix 1 of the December 31, 1987 submittal, and does not include the 10 riser velds which were permanently removed during the safe end and riser replacement. The correct number of IGSCC susceptible veldmen;s for unit 2 is 180, as reflected by the contents of Table 1. This informat' on is summarized below.
NUREG-0313 Inspection PIPING WELDS Number Category Resistant velds . . . . . . . . . . . . . .26 . . . . . . . . .A Welds with SI after 2 years of operation . .54 . . . .. ,. . .C Inspected, nonresistant welds . . . . ...6. . . .. . . . .D Cracked welds with IHSI or overlay . . . . .6. . . .. . . . .E Uninspected, nonresistant welds . . . . . . 76*. . . . . . . . .G TOTAL , . . . . . . . . . . . . . . . .. .168
- Includes 71 velds that were not inspected following IHSI; however, they were inspected before IHSI and found not to be cracked.
RECIRCULATION INLET SAFE ENDS Resistant Components . . . . . . . . . . . .10 . . . . . . . . .A JET FUMP INSTRUMENTATION SAFE ENDS Resistant velds . . . . . . . . . . . . . . .2 . . . .. . . . .A
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1.3.3 Plans for Future Mitization and Repairs In order to improve the resistance of the unit 2 veldments to IGSCC, several mitigation measures remain to be implemented during future outages. Hydrogen water chemistry is planned for installation during or before the cycle 6 ,
refueling outage. Also during the cycle 6 outage, the inaccessible welds in the RHR and RWCU penetrations will.either be removed, be clad with corrosion resistant material, or have local leak detection applied. Removal or corrosion resistant clad will include welds DRHR-2-3 and DRHR-2-12, which are immediately outside of the RHR penetrations and have not yet been mitigated.
Stress improvement will be applied to six Core Spray welds currently in category D, welds TCS-2-405, TCS-2-406, TCS-2-410, TCS-2-421, TCS-2-422, and-TCS-2-426. These velds are csrbon steel piping to stainless castings, and were inadvertently omitted from the earlier IHSI work scopes. Finally, the 71 welds which did not receive post-IHSI inspections, approximately 44 percent of the total IHSI workscope, will be inspected and thereby upgraded to inspection category C. Any welds in category G due to inadequate examination will ,
receive a code acceptable UT examination or radiographic examination and will be appropriately upgraded. Currently, full scale replacement of the IGSCC susceptible piping is not being considered for unit 2. Since the plans discussed here will not be implemented unti: the cycle 6 outage, they will have no immediate effect on the mitigation status of the welds or the cycle 6 inspection plan.
1.3.4 Resolution of Radiographic Indication la Weld DSRHR-2-5A In the December 1987 response to Generic Letter 84-11 (see section 1.3.1), the discovery of a radiographic indication in veld DSRHR-2-SA was described. This weld was radiographed early in the unit 2 outage because the baseline radiographs could not be found. The radiographs revealed linear indications located 0.2 and 0.6-inch below the outside surface. It was concluded from the radiographs and supplemental ultrasonic examinations that the indications were not IGSCC but instead were due to a lack of fusion between veld layers and had no appreciable through wall dimension. Because this was determined to be an ASME Code acceptability issue rather than an IGSCC issue, the analysis of this weld for continued operation was excluded from the GL 84-11 response. In response to the question raised by D. Smith, Office of Special Projects, at the May 11, 1988, meeting between the NRC Office of Special Projects and Browns Ferry Site Licensing, the indications exceeded Code allowable limits.
However, given that this is not an IGSCC issue, the analysis of this weld for continued operation will be submitted in a separate document.
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1.4.0 Unit 3 -
1.4.1 Summary of Insoections The IGSCC susceptible veldments of unit 3 vere inspected in accordance with the requirements of IE Bulletin 83-02 in 1983. Following the application of IHSI to 148 velds in March, 1984, 25 percent of the treated welds were re-examined. Four of the recirculation inlet safe ends were examined in October 1987, and these examinations will be completed before unit startup.
1.4.2 Summary of Mitization and Repair Activities A detailed technical description of the inspections, repairs, and mitigation measures implemented on r.ie unit 3 piping system veldments was submitted to Mr. Harold Denton, Direstor of the Office of Nuclear Reactor Regulation, on August 9, 1984, docke; number 50-296. The mitigation and repair status of the unit 3 velds is summarized below. .
NUREG-0313 Inspection PIPING WELDS Number Catego ry Welds with SI after 2 years of operation . 42. .. . . . . . .C Inspected, nonresistant velds . . . . . . . 11. .. . . . . . .D Noninspected, nonresistant velds *. . . . . .120 . . . . . . ..G TOTAL . . . . . . . .. . . . . . . . . . . 173
- Includes 106 velds that were not inspected following IHSI RECIRCULATION INLET SAFE ENDS Cracked, unmitigated components. . . . . . 4. .. . . . . . .F Noninspected, nonresistant components . . . .6 . .. . . . . . .G TOTAL . . .. ... . ... . . . ... . . 10 JET PUMP INSTRUMENTATION SAFE ENDS Cracked welds with adequate overlays. . . . 4 . ... . . . . .E Inspected, nonresistant velds . . . . . . . .6... . . . . . .D 1.4.3 Plans for Additional Mitigation and Repair Activities Several additional mitigation measures are planned for implementation before unit 3 startup. Ten of the velds now categorized as G, uninspected and nonresistant, vill receive IHSI treatments followed by inspections and so will be upgraded to category C. The 106 velds which were not inspected following IHSI will be inspected, and thereby upgraded to category C. The uninspected
recirculation inlet safe ends will be inspected, and repair or replacement will be implemented as required. The inaccessible welds in the RHR and RWCU penetrations will be removed, clad with corrosion resistant material, or have local leak detection applied. These activities will include the welds immediately outside of the penetrations which have not yet been mitigated.
Finally, a permanent hydrogen water chemistry system will be installed to provide an additional level of mitigation for all primary components. :
Currently, a large scale piping replacement is not being considered for unit 3.
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-9 2.0 Inservice Inspection Program Plans -
In order to ensure that future inspections performed on the austenitic stainless steel piping described in section 1.1.0 conform to the NRC staff positions on methods, personnel, schedules, and expansion plans, the BFN ISI program plans are currently being revised.
To address the changes in methods and personnel requirements, Procedure Change Requests (PCR) have been initiated to add the Electric Power Research Institute-developed personnel qualification requirements to *he procedures listed below.
N-UT-25 "UT Examination of Piping Welds for the Detection of Low-Level Cracklike Reflectors Originating at the ID Surface" N-UT-42 "UT Examination Using the Intraspect 98 System for the Detection of Intergranular Stress Corrosion Cracking in Piping Weldments" N-UT-28 "UT Examination of Backlay Weld Repairs" ,
BF-UT-29 "UT Examination of Backlay Weld Repaired Piping Welds" The following excerpt from the PCR revising N-UT-28 indicates the manner in which these requirements vill be incorporated:
"Level II and III individuals shall have successfully completed the veld overlay qualification examination at the Electric Power Research Institute or other approved agencies."
The sizing procedures, which are currently under development, vill also include the EPRI-developed performance demonstration personnel qualification requirement.
To address the NUREG requirements for inspection schedules and expansion plans, the BFN IGSCC susceptible veldments have been categorized according to Table 1, given in section 5 of the NUREG. The veld categories vill be updated as additional mitigation activities are performed. Using these categories, inspection schedules have been or vill be developed for the cycle 6 refueling outage (RFO) of each unit. These inspection plans and their schedules for submittal are discussed in the sections below.
2.1.0 Unit 1 ISI Plan for the Cycle Six Refueline Outare (RFO)
BFN Unit 1 was shut down following the completion of cycle 5 in 1985; however, the work scheduled to be performed during the cycle 6 RF0 has not yet been initiated. Before the unit 1 vork begins, the decision regarding pipe replacement vill be made. If pipe replacement is chosen no inspections vill be performed on the existing piping, if the IGSCC mitigation alternatives to replacement are chosen, the current inservice inspection plan vill be updated to reflect the requirements of GL 88-01. It is understood that these inspection guidelines supersede previous requirements and commitments. Once l this plan has been submitted to NRC, it vill be implemented on the existing piping before the mitigation activities are implemented. Following completion
- of all repair or replacement work, a report containing the details of the work i
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will be submitted for NRC approval before the unit startup in order to meet the intent of GL 88-01. This report will also contain the ISI plan for the cycle 7 RTO, which will reflect the improved mitigation status of the piping welds.
2.2.0 Unit 2 ISI Plan for the Cvele Six Refuelinz Outage The cycle 5 RF0 work is currently being completed on BFN Unit 2 in preparation for startup. The ISI plan given in Appendix 1 was developed for implementation during the Cycle 6 RFO.
2.3.0 Unit 3 ISI Plans for Cvele Six Refuelinz Outagg BFN Unit 3 was shut down following three months of Cycle 6 operation. No refueling activities will be performed during this shutdown period. The current shutdown period, therefore, does not constitute a refueling outage. .
Several mitigation activities are planned for implementation during the ,
current shutdown period. As mitigations and repairs are implemented, the ISI plans for the cycle 6 RF0 will be developed to reflect the improved status of the welds in accordance with the guidelines given in GL 88-01. A report of the mitigation implementations as well as the cycle 6 ISI plan will be submitted for NRC approval before unit startup.
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3.0 DEMONSTRATION OF CONFORMANCE TO THE I&I REQUIREMENTS OF GL 88-01 GL-88-01 calls for a change to the technical specification section on ISI to state that the ISI program for piping covered by the scope of the GL will be in conformance with the staff positions therein expressed. In response to this request, the following statement will be requested to be added to the unit 2 technical specification regarding ISI before restart:
"The Inservice Inspection Program for piping identified in NRC Generic Letter 88-01 shall be performed in accordance with the staff positions on schedule, methods and personnel, and sample expansion included in this generic letter."
4.0 TECHNICAL SPECIFICATION CONFORMANCE TO STAFF POSITIONS ON LEAK DETECTION The technical specifications for all three BFN units have been changed to comply with the leak detection requirements stated in Generic Letter 84-11. ,
The technical specification changes were submitted to NkC in a memorandum from J. A. Domer (TVA) to D. R. Miller (NRC) dated December 15, 1986. NRC approved the proposed changes in a letter from John A. Zwolinski (NRC) to S. A. White (TVA) dated August 26, 1987. The changes made to the technical specifications at that time satisfy the requirements of Generic Letter 88-01, as shown in Appendix 2. No additional actions are required in this matter. BFN will monitor leakage according to the referenced technical specifications. -
5.0 PLANS TO NOTIFY NRC 0F FLAWS In the past, NRC has been notified of the inspection results, flaw evaluations, and repair and mitigation measures associated with the BFN units through a comprehensive report submitted before plant startup. This report entitled the "Browns Ferry Unit 2 Cycle 5 Report of Pipe Inspections, Corrective Actions, and Analyses," was submitted December 31, 1987. BFN plans to continue this mode of communication. Following completion of the IGSCC mitigation work scope on unit 3, a report of those activities will be submitted before unit restart to supplement this response. This will include the ISI program plan for the cycle 7 RFO. Similarly, a report of the unit 1 cycle 6 inspections, mitigations and repairs will be submitted before unit 1 restart. After the IGSCC mitigation work scopes have been fully implemented, l
reports.will be made only in the event of the discovery of new flaws, or a change found in the condition of flaws previously detected. In these instances, a full ~ report of tlie flaw evaluation and the otrategy and technical l justification for repair or continued operation will be submitted.
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NOTES TO TABLE 1
- - A carbon content of 0.000 indicates that the carbon content information was unavailable for that veld. .
.ending date of the latest ISI effort in which the veld was inspected.
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T 07/07/88 TABLE 1 BFN UNIT 2 IGSCC INSPECTION AND MITIGATION
SUMMARY
- NU-ISI REG CARBON DATE CONTENT LAST CALL IGSCC CAT-WELD ID PIPE PIPE EGORY SIZE CONFIG
- ISI** *** MITIGATION NUMBER 12 P-SE 0.043 09/30/87 OK REPLACED + IHSI A 2RK6 12 P-3 0.063 09/30/87 OK REPLACED + IHSI A 2RKS GR-2-09 12 SOL-P 0.060 04/30/85 OK IHSI C 12 P-SE 0.043 09/30/87 OK REPLACED + IHSI A 2RJ6 REPLACED + IHSI A 2RJ5_ 12 P-E 0.065 09/30/87 OK GR-2-12 12 SOL-P 0.060 04/30/85 OK IHSI C 2RH6 12 P-SE 0.043 09/30/87 10K REPLACED + IHSI A
.2RHS 12 P-E 0.063 09/30/87 OK REPLACED + IHSI A GR-2-15 12 R-P 0.060 09/30/87 100% IHSI o OVERLAY E 2RG6 12 P-SE 0.043 09/30/87 OK REPLACED + IHSI A 2RG5 12 P-E 0.070 09/30/87 OK REPLACED + IHSI-A 0.070 12/31/84 OK IHSI d GR-2-19 12 SOL-P 2RF6 12 SE-P 0.043 09/30/87 OK REPLACED + IHSI A 2RF5 12 P-E 0.070 09/30/87 OK REPLACED + IHSI A GR-2-22 12 SOL-P 0.070 12/31/84 OK IHSI C 2RA6 12 P-SE 0.043 09/30/87 OK REPLACED + IHSI A 2RA5 12 P-E 0.063 09/30/87 OK REPLACED + IHSI A GR-2-35 12 SOL-P 0.054 12/31/84 OK IHSI C 2RB6 12 P-SE 0.043 09/30/87 OK REPLACED + IHSI A 2RBS 12 P-E 0.065 09/30/87 OK REPLACED + IHSI A GR-2-38 12 SOL-P 0.054 12/31/84 OK IHSI C 2RC6 12 P-SE 0.043 09/30/87 OK REPLACED + IHSI A 2RC5 12 P-E 0.065 09/30/87 OK REPLACED + IHSI A GR-2-41 12 R-P 0.060 12/31/84 OK IHSI C 12 P-SE 0.043 09/30/87 .OK REPLACED + IHSI A 2RD6 12 P-E 0.063 09/30/87 OK REPLACED + IHSI A 2RD5 GR-2-45 12 SOL-P 0.062 12/31/84 OK IHSI C 12 P-SE 0.043 09/30/87 OK REPLACED + IHSI A 2RE6 12 P-E 0.065 09/30/87 OK REPLACED + IHSI A 2RES GR-2-48 12 SOL-P 0.062 12/31/84 OK IHSI C
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- 22 P-C 0.070 04/30/85 OK IHSI C
.<-2-14 22 P-SOL 0.060 12/31/84 15% IHSI E 22 P-SOL 0.060 12/31/84 OK IHSI C
..R-2~13 IHSI C
.R-2-12 22 X-P 0.060 12/31/84 OK 22 X-R 0.060 09/30/87 OK IHSI C KR-?-11 IHSI C GR-2-18 22 X-P 0.060 04/30/85 OK 22 P-SOL 0.060 12/31/84 OK IHSI C KR-2-19 IHSI C KR-2-20 22 P-SOL 0.060 12/31/84 OK P-V 0.034 12/31/84 OK IHSI C GR-2-25 22 IHSI C GR-2-26 22 V-P 0.050 12/31/84 OK 22 V-P 0.050 12/31/84 OK IHSI C GR-2-52 IHSI C GR-2-51 22 P-V 0.034 04/30/85 OK 22 P-SOL 0.060 12/31/84 OK IHSI C KR-2-42 IHSI E KR-2-41 22 P-SOL 0.060 12/31/84 12%
22 X-P 0.070 12/31/84 OK IHSI C GR-2-44 IHSI C KR-2-33 22 X-R 0.070 09/30/87 OK
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'Page No. 2' 07/07/88 TABLE 1 BFN UNIT 2 IGSCC INSPECTION-AND MITIGATION
SUMMARY
- NU-CARBON DATE ISI REG WELD ID PIPE PIPE CONTENT LAST CALL IGSCC CAT-HUMBER SIZE CONFIG
- ISI** *** -MITIGATION EGORY KR-2-34 22 X-P 0.070 04/30/85 OK IHSI C KR-2-35 22 P-SOL 0.060 04/30/85 OK IHSI C KR-2-36 22 P-SOL 0.060 12/31/84 26% IHSI E KR-2-37 22 P-C 0.070 12/31/84 20% IHSI E
-GR-2-8' 28 T-X 0.060 09/30/87 OK (RT) IHSI C KR-2-3 28 P-T- 0.064 12/31/84 OK IHSI C KR-2-1 4X28 WOL-P 0.064 04/30/85 OK (RT) IHSI C KR-2-4 4X28 WOL-P 0.064 04/30/85 OK (RT) IHSI C KR-2-2 28 E-P 0.064 04/30/85 OK IHSI C
-GR-2-3 28 V-E 0.052 12/31/84 OK IHSI C
> GR-2-2 28 P-V 0.064 12/31/84 OK IHSI C, GR-2-1 28 PMP-P 0.064 04/30/85 OK IHSI C GR-2-58 28 E-FMP 0.055 12/31/84 OK IHSI C KR-2-48 28 P-E 0.055 12/31/84 OK IHSI C KR-2-49 6X28 P-FLN 0.055 12/31/84 OK IHSI C GR-2-57 28 V-P 0.055 12/31/84 OK IHSI C GR-2-56 28 E-V 0.062 12/31/84 OK IHSI C KR-2-47 28 P-E 0.062 12/31/84 OK IHSI C KR-2-46 28 T-P 0.063 12/31/84 OK IHSI C GR-2-55 28 P-T 0.064 12/31/84 OK IHSI C GR-2-54 28 E-P 0.064 12/31/84 OK IHSI C KR-2-45 28 P-E 0.064 04/30/85 OK IHSI C GR-2-53 28 SE-P 0.064 12/31/84 OK IHSI C
! GR-2-7 4X28 WOL-C 0.060 09/30/87 OK (RT) IHSI C GR-2-4 4X28 WOL-C 0.060 09/30/87 OK (RT) IHSI C GR-2-34 28 T-X 0.070 09/30/87 OK (RT) IHSI C KR-2-25 28 P-T 0.064 12/31/84 OK IHSI C KR-2-26 4X28 P-WOL 0.064 04/30/85 OK (RT) IHSI C KR-2-24 28 E-P 0.064 12/31/84 OK IHSI C GR-2-29 28 V-E 0.053 12/31/84 OK IHSI C GR-2-28 28 P-V 0.064 12/31/84 OK IHSI C KR-2-23 4X28 P-WOL 0.064 04/30/85 OK (RT) IHSI C GR-2-27 28 PMP-P 0.064 12/31/84 OK IHSI C GR-2-64 28 E-FMP 0.056 04/30/85 OK IHSI C KR-2-52 28 P-E 0.056 12/31/84 OK IHSI C KR-2-53 6 P-FLN 0.055 12/31/84 OK IHSI C GR-2-63 28 V-P 0.055 12/31/84 OK IHSI C GR-2-63B 5X28 WOL-P 0.055 12/31/84 OK IHSI C GR-2-63A 5 WOL-C 0.060 12/31/84 OK IHSI C GR-2-62 28 E-V 0.055 04/30/85 OK IHSI C KR-2-51 28 P-E 0.057 12/31/84 OK IHSI C
! GR 2-61 28 P-P 0.064 12/31/84 OK IHSI C GR-2-60 28 E-P 0.064 04/30/85 OK IHSI C KR-2-50 28 P-E 0.064 12/31/84 OK IHSI C GR-2-59 28 SE-P 0.064 12/31/84 OK IHSI C GR-2-33 4 WOL-C 0.060 09/30/87 OK (RT) IHSI C
. Page No. 3 07/07/88 TABLE 1 BFN UNIT 2 IGSCC INSPECTION AND M1TIGATION
SUMMARY
NU-CARBON DATE ISI REG WELD ID PIPE PIPE CONTENT LAST CALL IGSCC CAT-NUMBER SIZE CONFIG
- ISI** *** MITIGATION EGORY GR-2-30 4 WOL-C 0.060 09/30/87 OK (BT) IHSI C DRHR-2-13 24 E-P 0.060 12/31/84 OK IHSI C DRHR-2-14 24 P-E 0.060 12/31/84 OK IHSI C DRHR-2-15 24 V-P 0.039 12/31/84 OK IHSI C DSRHR-2-6 24 P-P 0.039 04/30/85 OK IHSI C DSRHR-2-7 24 E-P 0.039 12/31/84 OK IHSI C DBHR-2-16 24 V-P 0.060 12/31/84 OK IHSI C DBHR-2-17 24 V-P 0.039 04/30/85 OK IHSI C DRHR-2-18 24 T-P 0.039 12/31/84 OK IHSI C DRHR-2-4 24 E-P 0.060 04/30/85 OK IHSI C DRHR-2-5 24 E-V 0.060 12/31/84 OK IHSI C, DRHR-2-6 24 V-P 0.039 04/30/85 OK IHSI C DSRHR-2-3 24 P-P 0.039 12/31/84 OK IHSI C DSRHR-2-4 24 E-P 0.039 04/30/85 OK IHSI C DRHR-2-7 24 V-P 0.060 12/31/84 OK IHSI C DRHR-2-8 24 V-P 0.039 12/31/84 OK IHSI C DRHR-2-9 24 T-P 0.039 12/31/84 OK IHSI C DSRHR-2-1 24 E-P 0.039 12/31/84 OK IHSI C DSRHR-2-2 24 E-P 0.039 12/3),'84 OK IHSI C DSRHR-2-4A 24 E-E 0.060 12/31/84 OK IHSI C DSRHR-2-5 24 E-P 0.039 04/30/85 OK IHSI C DSRHR-2-5A 24 E-P 0,039 12/31/84 OK IHSI C DRHR-2-3 24 P-V 0.060 12/31/84 OK NONE A DRHR-2-12 24 P-V 0.060 12/31/84 OK HONE A DRFR-2-13B 24 P-P 0.060 / / PEN NONE A DRHR-2-3B 24 P-P 0.060 / / PEN NOME A DRHR-2-19 20 T-P 0.047 12/31/84 OK IHSI C DSRHR-2-9 20 E-P 0.047 04/30/85 OK IHSI C DRHR-2-21 20 V-E 0.060 12/31/84 OK IHSI C DRHR-2-22 20 V-P 0.047 12/31/84 OK IHSI C DSRHR-2-10 20 E-P 0.047 12/31/84 OK IHSI C DSRHR-2-8 20 SOL-P 0.060 04/30/85 OK IHSI C DSRHR-2-11 20 E-P 0.047 12/31/84 OK IHSI C DRHR-2-23 20 V-P 0.047 12/31/84 OK IHSI C DRWC-2-5B 6 V-P 0.000 04/30/85 OK IHSI C DRWC-2-5A 6 P-FH 0.000 09/30/87 OK IHSI C DRWC-2-4X 6 P-E 0.000 04/30/86 OK HSW A DRWC-2-4A 6 P-P 0.000 04/30/86 OK HSW A DRWC-2-4b 6 P-P 0.000 04/30/86 OK HSW A DSRWC-2-7X 6 P-E 0.000 04/30/86 OK HSW A DRWC-2-7A 6 P-P 0.000 04/30/86 OK HSW A DRWC-2-7B 6 P-P 0.000 04/30/86 OK HSW A DSRWC-2-6 6 P-E 0.000 10/31/86 OK IHSI C DSRWC-2-5 6 P-E 0.000 05/31/87 70% IHSI + OVERLAY E DSRWC-2-4 6 P-E 0.000 10/31/86 OK IHSI C DSRWC-2-3 6 P-E 0.000 09/30/86 OK I!!SI C
Pcgo No. 4 07/07/88 TABLE 1 BFN UNIT 2 IGSCC INSPECTION AND MITIGATION
SUMMARY
- NU-CARBON DATE ISI REG WELD ID PIPE PIPE CONTENT LAST CALL IGSCC CAT-HUMBER SIZE CONFIG
- ISI** *** MITIGATION EGORY DSRWC-2-2 6 P-E 0.000 10/30/86 OK IHSI C DSRWC-2-1A 6 P-3 0.000 11/30/86 OK IHSI C DRWC-2-3 6 P-V 0.000 11/30/86 OK IMSI C DRWC-2-2 6 V-3 0.000 11/30/86 OK IHSI C DSRWC-2-1 6 E-P 0.000 01/31/85 OK IHSI C DRWC-2-1 6 P-V 0.000 03/31/85 OK IHSI C DRWC-2-1A 6 V-P 0.000 09/30/86 OK IHSI C DSRWC-2-1B 6 P-SOL 0.000 12/31/84 OK IHSI C DRWC-? 6 P-P 0.000 / / PEN NONE A TCS-2-417 10 SE-N 0.000 09/30/87 OK IHSI C TSCS-2-418 10 SE-P 0.000 09/30/87 OK IHSI C DCS-2-5 12 P-V 0.000 04/30/85 OK IHSI C' DSCS-2-2 12 P-E 0.000 12/31/84 OK IHSI C DSCS-2-1 12 E-P 0.000 12/31/84 OK IHSI C DCS-2-4 12 P-P 0.000 12/31/84 OK IHSI C TCS-2-401 12 SE-N 0.000 09/30/87 OK IHSI C TCS-2-403 12 SE-P 0.000 09/30/87 OK IHSI C DCS-2-14 12 P-V 0.000 12/31/84 OK IHSI C -
DSCS-2-9 12 P-2 0.000 12/31/84 OK IHSI C DCS-2-7 12 P-E 0.000 04/30/85 OK IHSI C DCS-2-13A 12 P-P 0.000 12/31/84 OK IHSI C DCS-2-13 12 P-P 0.000 04/30/85 OK IHSI C N1A-2 28 N-SE 0.000 09/30/87 OK IHSI C N1B-2 28 N-SE 0.000 09/30/87 OK IHSI C 2RA1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 2RB1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 28C1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 2RD1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 2RE1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 2RF1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 2RG1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 2RH1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 2RJ1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A 2RK1 12 N-SE 0.000 09/30/87 CC REPLACED + IHSI A TCS-2-405 12 R-V 0.000 12/31/84 OK NONC TCS-2-406 12 V-P 0.000 12/31/84 OK NONE TCS-2-410 12 E-V 0.000 12/31/84 OK NONE TCS-2-421 12 R-V 0.000 12/31/84 OK HONE TCS-2-422 12 V-P 0.000 12/31/84 OK NONE TCS-2-426 12 E-V 0.000 12/31/84 OK HONE JP-2-1A 0.000 05/15/85 OK REPLACED 316HG A JP-2-1B 0.000 05/15/85 OK REPLACED 316HG A
1 1
1 l
i APPENDIX 1 1
ISI PPCGPAM PLANS FCP BFN UNIT 2 CYCLE 6 PFC 1 .
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t e e 1 6S l s ad tl 0 6 7 2 4 7 6 S 1 3 5 oe 2 2 1 4 2 Tw d
_ mo ah T T r T T T T T T T T wt U U T t U U U U U U U U L ee t
el d r oi ,
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E 1 1 1 1 1 1 1 1 1 1 x.1 t s s
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go r eg A A C C C 0 D E t C c
- s. et na C
m m m m m s r e n r e t e s r e n t e e et o et at e et o at l t s i t s es l t s i es s t a y t ay H y y y t a y t H y t a wS a wS S a a a wS a S l r r l l l c l r p l
r p at p p u r p u at e u u cm cm o ua n Gcm ou cm oe ua S m e
S m e r e t n r e d v n Fr e t n r e t n ca d v et et it ca it io e Ii t ca it ae io sm r s r s cs ae cs sm m tcs ae cs ey el ee oy oy e y el ey ee o i ey el p C R D 0 c FRS R C sS RC D R CS CS R S D S 8
. . . . . . . 6 K 0 1 A B c D 5 F C H 1 J 3
l[l I I (l 1
i 4
AUCMENTED EXAMINATION SCHEDULE CENERIC LETTER 88-01, WUREG-0313 R2 BFN UNIT 2 NuReg Sect.XI Coje Eram Tot $,'4th RFO 7th RTO 8th RFO 9th RFO loth R.'O lith RFO 12th h(O
_Coeroments Ca hgaty Clas21E2Ulli Meth9d Hilds SDP21t_ Ese21m_ Sae21c_ SMPle_ Saesle_ Saenle_._ S ac21e_ l Reference Drasjna
.._lante s .
coments I. rJr2Nf, (Con't)
Feactor Water G 1 UT 2 2 * * * * * *
. CHM-2073-C Cat. pubject to Cleanup Systen change after esam M. Core Spray G 1 trr 6 6 * * * * *
- CID4-2071-C Cat. subject to System change after esam II. COMECEtrIS A. Recirculation A 1 UT 10 1 - 1 - 1. -
1 ISI-0270-C Resistar t Materiale Inlet Safe End ,
- 6. Jet Purnp Instr. A , 1 UT 2 - - - 1 - - -
ISI-0156-A Resistant Materials Safe Ends I
taOTES : .
(1) All welds in non-resitt ant material should be inspected af ter a stress improvement process as part of the process. Schedule" shown should be followed after this lettial irspection.
(2) See reconenendations for accei table weld overlay reinforcements and stress improvement mitigation.
(3) Welds that are not UT lospectable should be replaced, "sleeved", or local leak detection applied. RT esamination or visual inspection for leakage may also be considered.
I 30600 t
APPENDIX 2 TECHNICAL SPECIFICATION RELATED TO REACTOR COOLANT LEAKAGE The following technical specification changes will be submitted for formal NRC review prior to restart.
These pages are provided herewith to temonstrate intended technical specification changes to satisfy Generic Letter 88-01.
.. -. . . - _. . . - -~ _ .- _- .- .
,., ., G L 8 8 - 0 1_-_ R E Q U I R E M E N T -
BFN TECH SPEC
- 1. Pltr.t shutdown within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> See attached, section 3.6.C if:
increase in-leak rate 1 2 gpm or total ~ unidentified leakage = 5 gpm
- 2. Sump level monitoring interval: See attached, section 4.6.C.
1 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />s-
- 3. For plants having category See attached, section 3.6.c.
D,E,F, or G welds:
one leakage measurement instrument shall be operable and outage time for inoperable instruments shall be 1 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> w
S w he l
l l
t
o -
ATTACHMENT TO LICENSE AMENDMENT NO.133 FACILITY OPERATING L: CENSE N0.'DPR-52 DOCKET NO. 50-260 Revise the Appendix A Technical Specifications by removing the pages identified below and inserting the enclo:ed pages. The revised pages are identified by the captioned amendment number and contain marginal lines indicating the area of change.
REMOVE INSERT 3.6/4.6-9 3.6/4.6-9 3.6/4.6-10 3.6/4.6-10
.48 9
, ,v - ,--,,--r.- ----r-,,,,-u-- ---.---e,wv---- --
o l
l 3.6/4.6 PRIMARY SYSTEM BOUNDARY l LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.6.C. Coolant Leakate 4.6.C. Coolant Leakare
- 1. a. Any time irradiated 1. Reactor coolant fuel is in the system leakage shall reactor vessel and be checked by the reactor coolant sump and air sampling temperature is above system and recorded 212*F, reactor coolant at least once per leakage into the 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
primary containment from unidentified sources shall not exceed 5 gpm. In addition, the total reactor coolant system leakage into,the .
shall not exceed 25 spm.
- b. Anytime the reactor is in RUN mode, reactor coolant leakage into the primary containment from unicantified sources shall not increase by more than 2 spm averaged over any 24-hour period in which the reactor is in the RIrN mode except as defined in 3.6.C.I.c below,
- c. During the first 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> in the RUN mode following STARTUP, an increase in reactor coolant leakage into the primary conta!.iment of >2 spm is acceptable as long as the requirements of 3.6.C.1.a are met.
1 l
BFN ' 3.6/4.6-9 AMEN 0 MENT NO. 133 Unit 2 '
A
l 3.6/4.6 PRIMARY SYSTEM BOUNDARY LIMITING CONDITIONS FOR OPERATION SURVEILLANCE REQUIREMENTS 3.6.C Coolant Leatate 4.6.C Coolant Leakage
- 2. Both the sump and air sampling 2. With the air sampling systems shall be OPERABLE during system INOPERABLE, grab reactor power operation. From samples shall be obtained and after the date that one of and analyzed at least once these systems is made or found every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
to be INOPERABLE for any reason, reactor power operation is permissible only during the succeeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for the sump system or 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> for the air sampling system.
The air sampling system may be removed from service for a "
period of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for calibration, function testing, and maintenance without providing a temporary
. monitor.
- 3. If the condition in 1 or 2 above cannot be met, an orderly shutdown shall be initiated and the reactor shall be shutdown in the Cold Condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
3.6.D. R,elief Valves 4.6.D. Relief Valves
- 1. When more than one relief valves 1. Approximately one-half of are known to be f ailed, an orderly shutdown shall be all relief valves shall be bench-checked or initiated and the reactor replaced with a depressurized to less than 105 bench-checked valve
! psig within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, each operating cycle.
All 13 valves will have
- been checked or replaced upon the completion of every second cycle.
- 2. Once during each operating cycle, each relief valve shall be manually opened until l thermocouples and i
acoustic monitors l downstream of the valve indicate steam is flowing from the valve.
g 3.6/4.6-10 ,
AMENDMENT N0. 133
. .