ML20238D740
| ML20238D740 | |
| Person / Time | |
|---|---|
| Site: | Beaver Valley |
| Issue date: | 08/27/1987 |
| From: | Sieber J DUQUESNE LIGHT CO. |
| To: | NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM) |
| References | |
| 2NRC-7-198, NUDOCS 8709110367 | |
| Download: ML20238D740 (5) | |
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$m T4tF Telephone (412) 393-6000 IEYoOl ""
August 27, 1987 Sh'PP'"0P P^ '5 77' d
2NRC-7-198 U. S. Nuclear Regulatory Commission Attn:
Document Control Desk Washington, DC 20555
Reference:
Beaver Valley Power Station, Unit No. 2 Docket No. 50-412, License NPF-73 Instrumented Inspection Technique (IIT)
Gentlemen:
Our letter dated April 22, 1986 requested NRC approval of the use of the Instrumented Inspection Technique (IIT) at Beaver Valley Power Station Units 1
and 2.
We also committed to forward the conclusions of the evaluation identifying the Beaver Valley Unit 2 systems where IIT may be implemented.
This evaluation has been completed and the results are presented below.
Please note that the NRC cranted approval for the use of IIT at Beaver Valley Unit 1 by lettex dated May 15, 1986.
The Beaver Valley Unit 2 plant systems identified below have been evaluated by HAFA International, Inc. in accordance with Section IV of HAFA Topical Report HAFA 135(P)(A) and this evaluation is available at the Beaver Valley site.
Based on these evaluations, it has been determined that IIT can be implemented on the appropriate portions of the following systems:
Chemical and Volume Control Residual Heat Removal Safety Injection Containment Depressurization (Recirculation Spray / Quench Spray)
Sampling Main Steam Auxiliary Feedwater Main Feedwater Steam Generator Blowdown Service Water Component Cooling Water Fuel Pool Cooling A
summary of the justifications for use of IIT in lieu of conventional hydrostatic testing is attached.
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B aver Valley Power Station, Unit No. 2 Docket No. 50-412, License NPF-73 Instrumented Inspection Technique (IIT)
Although we have chosen to conduct the ASME Section XI Code
" System Hydrostatic 7est" of IWA-5211(d) on the NSSS portion of the Reactor Coolant
- Systen, the IIT may also be implemented selectively within that boundary.
It should be noted that Duquesne light Company recognizes the capability of the IIT method to determine intersystem leakage, and therefore, may opt to take credit for this method to satisfy the Inservice Testing Program and Technical Specification requirements where appropriate, i
If there are any questions concerning this matter, please contact my office.
Since this letter provides the additional information committed to in our April 22, 1986 letter, no additional application fee is required.
Very truly yours,
)
J.
D. Sieber h"vicePresident, Nuclear cc: Mr. J. Beall, Resident Inspector U.
S. Nuclear Regulatory Commission Beaver Valley Power Station Shippingport, PA 15077 U.
S.
Nuclear Regulatory Commission Regional Admir.istrator Region 1 631 Park Avenue King of Prussia, PA 19406 Mr. Peter S. Tam U.
S. Nuclear Regulatory Commission Project Directorate No. 2 Division of PWR Licensing - A Washington, DC 20555
- Mail Stop 316 Addressee only Director, Safety Evaluation & Control Virginia Electric & Power Company P.O. Box 26666 One James River Plaza Richmond, VA 23261 l
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ATTACH' MENT
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SUMMARY
OF JUSTIFICATIONS FOR USE OF IIT IN LIEU OF CONVENTIONAL HYDROSTATIC TESTING
- 1.. Feedwater System, Main Steam System and Steam Generator Blowdown i
Hydrostatic pressure testing of the secondary system, including
. portions of main
- steam, feedwater and steam generator blowdown
- systems, requires an elevated test temperature to accommodate brittle fracture prevention criteria.
Test temperature and pressure must be held stable over a test duration of 7 to 9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> including time required for visual inspection.
Fifteen (15) code safety valves (3 loops, 5 code safeties per loop) must be removed and blanked, and check valve internals must be removed.
Reassembly, following
- testing, requires that a second test be run to ensure leak tightness of the disassembled components.
System configuration requires that most of the system be pressurized a second time for this purpose.
Temporary piping and connections are required between the hydrostatic test pump and several connection points within the system.
System configuration requires routing of these connections through certain high radiation and high contamination controlled access areas.
Installation and removal of these connections, and necessary cleaning and decontamination imposes additional radiation exposure.
2.
Auxiliary Feedwater Conventional hydrostatic testing has the potential to cause pump seal damage if unidentified leakage through the pump discharge valves is sufficiently 1&rge to impose a
reverse AP on the j
seals.
I 3.
Service Water Conventional hydrostatic testing has the potential to cause pump seal damage, requires relief valve gagging and pinning or removal 4
of check valve internals with a
subsequent component leakage j
test.
4.
Residual Heat Removal Conventional hydrostatic testing has the potential to cause pump seal damage and requires relief valve gagging or blanking and check valve internals pinning or removal with subsequent l
component leakage testing.
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ATTACHMENT (cont'd) 5.
Component Cooling water Conventional hydrostatic testing requires relief valve gagging and check valve internals pinning or removal with subsequent component leakage testing.
6.
Chemical and Volume control and safety Injection Conventional hydrostatic testing of portions of the systems;would require overpressurization of the Reactor Coolant System due to,a pressure isolation, has the potentlal]to to lack of any means of of low pressure piping due.
cause overpressurization unidentified intersystem leakage.
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7.
Containment Depressurization Conventional hydrostatic testing requires relief valve gging and has the potential to cause damage to instrumentation.
8.
Sampling Conventional hydrostatic testing requires relief valve gagging.
9.
Fuel pool Cooling Conventional hydrostatic testing requires subjecting the shell side of the fuel pool cooling heat exchangers to a pressure equal to 1.25 piping design pressure.
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