ML20236K212
| ML20236K212 | |
| Person / Time | |
|---|---|
| Site: | River Bend  |
| Issue date: | 08/03/1987 |
| From: | Calvo J Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20236K215 | List: |
| References | |
| TAC-65129, NUDOCS 8708070033 | |
| Download: ML20236K212 (19) | |
Text
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UNITED STATES
'8-NUCLEAR REGULATORY COMMISSION n
WASHINGTON, D. C. 20555 r
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GULF STATES UTILITIES COMPANY DOCKET NO. 50-458 RIVER BEND STATION, UNIT 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 7 License No. NPF-47 1.
The Nuclear Regulatory Commission (the Commission or the NRC) has found that:
A.
The application for amendment filed by Gulf States Utilities Company, dated March 10, 1987 as supplemented June 9, June 30, July.8, 23, and-27, 1987, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, the provisions of the Act, and the regulations of the Commission; C.
There is reasonable assurance:
(i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D.
The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.
'The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
2.
Accordingly, the license is amended by changes to the Technical Specifi-g cations as indicated in the attachment to this license amendment and
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paragraph 2.C.(2) of Facility Operating License No. NPF-47 is hereby
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amended to read as follows:
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(2) Technical Specifications and Environmental Protection Plan i
The Technical Specifications contained in Appendix A, as revised through j
Amendment No.7 and the Environmental Protection Plan contained in Appendix B, j
are hereby incorporated in the license.
GSU shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
8708070033 870B03 PDR ADOCK 05000450 P
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- 3.
This license amendment is effective as of its date of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION
'm d. (c L t =
l lJoseA.Calvo, Director Project Directorate - IV Division of Reactor Projects - III, IV, V and Special Projects Office of Nuclear Reactor Regulation
Attachment:
Changes to the Technical Specifications Date of Issuance: August 3, 1987
ATTACHMENT TO LICENSE AMENDMENT NO. 7 i
FACILITY OPERATING LICENSE NO. NPF-47 DOCKET NO.'50-458 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages.
The revised pages are identified by the captioned Amendment number and contain vertical lines indicating the area of change.
The corre-sponding overleaf pages are provided to maintain document completeness.
REMOVE INSERT 3/4 4-12 3/4 4-12 3/4 6-5 3/4 6-5 3/4 6-6 3/4 6-6 3/4 6-18 3/4 6-18 3/4 6-19 3/4 6-19 3/4 6-21 3/4 6-21 i
5
REACTOR COOLANT SYSTEM OPERATIONAL LEAKAGE l
LIMITING CONDITION FOR OPERATION 3.4.3.2 Reactor coolant system leakage shall be limited to:
l a.
b.
5 gpm UNIDENTIFIED LEAKAGE.
c.
25 gpm total leakage (averaged over any 24-hour period).
d.
0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm leakage at a reactor coolant system pressure of 1025 i 15 psig from any reactor coolant system pressure isolation valve specified in Table 3.4.3.2-1.
APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
a.
With any PRESSURE BOUNDARY LEAKAGE, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
b.
With any reactor coolant system leakage greater than the limits in b and/or c, above, reduce the leakage rate to within the limits within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
c.
With any reactor coolant system pressure isolation valve leakage greater than the above limit, isolate the high pressure portion of the affected system from the low pressure portion within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> by use of at least two other closed manual, deactivated automatic or check" valves, or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
d.
With one or more of the high/ low pressure interface valve leakage pressure monitors shown in Table 3.4.3.2-2 inoperable, restore the inoperable monitor (s) to OPERABLE status within 7 days or verify the pressure to be less than the alarm point at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />; restore the inoperable monitor (s) to OPERABLE status within 3D days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
The provisions of Specifi-cation 3.0.4 are not applicable.
- Which have been verified not to exceed the allowable leakage limit at the last refueling outage or after the last time the valve was disturbed, whichever is more recent.
RIVER EDs - talIT 1 3/4 4-11
i SURVEILLANCE REQUIREMENTS 4.4.3.2.1 The reactor coolant system leakage shall be demonstrated to be within each of the above limits by:
a.
Monitoring the drywell atmospheric particulate radioactivity at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, b.
Monitoring the sump flow rates at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, c.
Monitoring the drywell air coolers condensate flow rate at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, and d.
Monitoring the reactor vessel head flange leak detection system at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
4.4.3.2.2 Each reactor coolant system pressure isolation valve specified in Table 3.4.3.2-1 shall be demonstrated OPERABLE by leak testing pursuant to Specification 4.0.5 including paragraph IWV-3427(B) of the ASME Code and verifying the leakage of each valve to be within the specified limit:
a.
At least once per 18 months *, and l
b.
Prior to returning the valve to service following maintenance, repair or replacement work on the valve which could affect its leakage rate.
The provisions of Specification 4.0.4 are not applicable for entry into OPERATIONAL CONDITION 3.
l i
4.4.3.2.3 The high/ low pressure interface valve leakage pressure monitors I
shall be demonstrated OPERABLE with alarm setpoints per Table 3.4.3.2-2 by performance of a:
a.
CHANNEL FUNCTIONAL TEST at least once per 31 days, and b.
CHANNEL CALIBRATION at least once per 18 months.
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- This test may be performed during the refueling outage following the first cycle, scheduled to begin September 15, 1987.
l RIVER BEND - UNIT 1 3/4 4-12 Amendment No. 7
CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b.
If any periodic Type A test fails to meet 0.75 La, the test schedule for subsequent Type A tests shall be reviewed and approved by the Commission.
If two consecutive Type A tests fail to meet 0.75 La, a Type A test shall be performed at least every 18 months until two consecutive Type A tests meet 0.75 La, at which time the above test schedule may be resumed.
The accuracy of each Type A test shall be verified by a supplemental c.
l test which:
1.
Confirms the accuracy of the test by verifying that the difference between the supplemental test data and the Type A test data is within 0.25 La.
The formula to be used is:
[Lo + Lam - 0.25 La]
< Lc < [Lo + Lt.m + 0.25 La] where Lc = supplemental test results; Eo = superimposed leakage; Lam = measured Type A leakage.
2.
Has duration sufficient to establish accurately the change in leakage rate between the Type A test and the supplemental test.
3.
Requires the quantity of gas, injected into the primary containment l
or bled from the primary containment during the supplemental test, to be between 0.75 La and 1.25 La.
d.
Type B and C tests shall be conducted with gas at Pa, 7.6 psig*, at intervals no ' greater than 24 months ** except for tests involving:
l 1.
Air locks, 2.
Main steam positive leakage control system (MS-PLCS) valves and PVLCS valves, 3.
Penetrations using continuous leakage monitoring systems, l
4.
' Primary containment isolation valves in hydrostatically tested lines per Table 3.6.4-1 which penetrate the primary containment, and 5.
Purge supply and exhaust isolation valves with resilient material
- seals, Air locks shall be tested and demonstrated OPERABLE per Surveillance e.
Requirement 4.6.1.4.
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f.
Total sealing air leakage into the primary containment, at a test pressure of 11.5 psid for MS-PLCS valves and 33 psid for penetration leakage control system sealed valves, shall be detennined by test at least once per 18 months.** This _ leakage may be excluded when I
determining the combined leakage rate, 0.6 La.
- Unless a hydrostatic test is required per Table 3.6.4-1.
- This test may be performed during the refueling outage following the first cycle, scheduled to begin September 15, 1987.
RIVER BEND - UNIT 1 3/4 6-5 Amendment No. 7
I CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 9 Type B tests for electrical penetrations employing a continuous leakage I
monitoring system shall be conducted at Pa, 7.6 psig, at intervals no greater than once per 3 years.
h.
Leakage from isolation valves that are sealed with the PVLCS shall be tested once per 24 months with the valves pressurized to at least Pa, 7.6 psig. This leakage may be excluded when determining the combined leakage rate, 0.6 La.
i.
Primary containment isolation valves in hydrostatically tested lines per Table 3.6.4-1 which penetrate the primary containment shall be leak tested at least once per 18 months *.
l j.
Purge supply and exhaust isolation valves with resilient material seals shall be tested and demonstrated OPERABLE per Surveillance Requirement 4.6.1.9.3.
k.
The provisions of Specification 4.0.2 are not applicable to Speci fications 4.6.1.3.a. 4.6.1.3.d, 4.6.1.3.g, and 4.6.1.3. h.
- This test may be performed during the refueling outage following the first cycle, scheduled to begin September 15, 1937.
RIVER BEND - UNIT 1 3/4 6-6 Amendment No. 7 l
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CONTAINMENT SYSTEMS 3/4.6.2 DRYWELL DRYWELL INTEGRITY LIMITING CONDITION FOR OPERATION 3.6.2.1 DRYWELL INTEGRITY shall be maintained.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 28, and 3.
ACTION:
Without DRYWELL INTEGRITY, restore DRYWELL INTEGRITY within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.6.2.1 DRYWELL INTEGRITY shall be demonstrated:
At least once per 31 days by verifying that all drywell penetrations **,
a.
not capable of being closed by OPERABLE drywell automatic isolation valves and required to be closed during accident conditions, are closed by valves, blind flanges, or deactivated automatic valves secured in l
position, except as provided in Specification 3.6.4.
By verifying the drywell air lock is in compliance with the require-d b.
ments of Specification 3.6.2.3.
By verifying the suppression pool is in compliance with the require-c.
ments of Specification 3.6.3.1.
By verifying the drywell bypass leakage is in compliance with the d.
requirements of Specification 3.6.2.2.
- See Special Test Exception 3.10.1.
- Except valves, blind flanges, and deactivated auttraatic valves which are L
located inside the drywell or primary containment, and are locked, sealed or otherwise secured in the closed position.
These penetrations shall be verified closed during each COLD SHUTDOWN, except such verification need not be performed more often than once per 92 days.
I WIVER MIS - INIT 1 3/4 6-17
a CONTAINMENT SYSTEMS.
-SURVEILLANCE REQUIREMENTS (Continued) e.
By verifying the personnel door inflatable seal system OPERABLE by:
'1.
At least once per 7 days verifying seal air flask pressure to be greater.than or equal to 75 psig.
2.
At least once per 18 months
- conducting a seal pneumatic system l
leak test and verifying that system pressure does not decay more than 0.67 psig from 75 psig within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
- This test may be performed during the refueling outage following the first cycle, scheduled to begin September 15, 1987.
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RIVER BEND - UNIT 1 3/4 6-18 Amendment No. 7
CONTAINMENT SYSTEMS DRYWELL BYPASS LEAKAGE
' LIMITING CONDITION FOR OPERATION 3.6.2.2 Drywell bypass-leakage shall be less than or equal to 10% of the 2
acceptable A//E design value of 1.0 ft,
APPLICABILITY:
When DRYWELL INTEGRITY is required per Specification 3.6.2.1.
ACTION:
With the drywell bypass leakage greater than'10% of the acceptable A//E design value of 1.0 ft, restore the drywell bypass leakage to within the limit prior 2
to increasing reactor coolant system temperature above 200 F.
SURVEILLANCE REQUIREMENTS 4.6.2.2 At least once per 18 months *, the drywell bypass leakage rate test i
shall be conducted at an initial differential pressure of 3.0 psid and the A//E shall be calculated from the measured leakage.
One drywell airlock door shall remain open during the drywell leakage test such that each drywell door is leak tested during at least every other leakage rate test.
If any drywell bypass leakage test fails to meet the specified limit, a.-
the schedule for subsequent tests shall be reviewed and approved by the Commission.
If two consecutive tests fail to meet the limit, a test shall be performed at least every 9 months until two consecutive tests meet the limit, at which time the 18 month test. schedule may be resumed.
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- For the first cycle only, this may be extended to coincide with the refueling outage, scheduled to begin September 15, 1987.
RIVER BEND - 11 NIT 1 3/4 6-19 Amendment No. f, 7 1
4 CONTAINMENT SYSTENS BYWELL AIR LOCKS LINITING CONDITION FOR OPERATION
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l 3.6.2.3 The drywell air lock shall be OPERA 8LE with:
Both doors closed except that, when the air lock is being used for normal a.
transit entry and exit through the drywell, at least one air lock door sha'll be closed, and b.
An overall air lock leakage rate of less than or equal to 11.85 scf per hour at 3.0 psid, and The inflatable seal system air flask pressure 1 75 psig.
c.
I APPLICABILITY:
OPERATIONAL CONDITIONS 1, 28, and 3.
ACTION:
With one drywell air lock door inoperable:
I a.
1.
Maintein at least the OPERABLE air lock door c'losed and either
' restore the inoperable air lock door to OPERA 8LE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or lock the OPERABLE air lock door closed, Operation say then continue provided that the OPERABLE air lock door is verified to be locked closed at least once per 31 days. Otherwise, be in at least HOT SHUT 00WN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUT 00WN
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within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
2.
The provisions of Specification 3.0.4 are not applicable.
With the drywell air lock inoperable, except as a result of an inoperable b.
air lock door, maintain at least one air lock door closed; restore the l
inoperable air lock to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least I
HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
With one inoperable drywell air lock door inflatable seal system air flask
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pressure instrumentation channel, restore the inoperable channel to OPERABLE 1
status within 7 days or verify air flask pressure to be 175 psig at l
1 east once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
- see Special Test Exception 3.10.1.
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RIVER SHS - 4EET 1 3/4 6-20
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CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.2.3 The drywell air lock shall be demonstrated OPERABLE:
a.
Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> following each closing, except when the air lock is being used for multiple entries, then at least once per 72 hears, by verifying seal leakage rate less than or equal to 4.05 scf per hour when the gap between the door seals is pressurized to 3.0 psid.
- b.
- By conducting an overall air lock leakage test at 3.0 psid and veri-fying that the overall air lock leakage rate is within its limit:
1.
Each cold shutdown if not performed within the previous 6 months #.
2.
Prior to establishing DRYWELL INTEGRITY when maintenance has been perfomed on the air lock that could affect the air lock sealing capability.
c.
By verifying, prior to drywell entry if not performed within the past 18 months, that only one door in the air lock can be opened at a time.
d.
By verifying the door inflatable seal system OPERABLE by:
1.
At least once per 7 days verifying seal air flask pressure to be greater than or equal to 75 psig.
2.
At least once per 18 months
- conducting a seal pneumatic system l
leak test and verifying that system pressure does not decay more than 0.67 psig from 75 psig within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
- At least once per 18 months, the air lock will be pressurized to 19.2 psid prior to conducting the overall air lock test.
- This test may be performed during the refueling outage following the first cycle scheduled to begin September 15, 1987.
RIVER BEND - UNIT 1 3/4 6-21 Amendment No. 7 N
CONTAINMENT SYSTEMS DRYWELL-STRUCTURAL INTEGRITY LIMITING CONDITION FOR OPERATION 3.6.2.4 The structural integrity of the drywell shall be maintained at a level consistent with the acceptance criteria in Specification 4.6.2.4.
APPLICA8ILITY:
OPERATIONAL CONDITIONS 1, 2, and 3.
ACTION:
With the structural integrity of the drywell not conforming to the above requirements, restore the structural integrity to within the limits within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.6.2.4.1 The structural integrity of the exposed accessible interior and exterior surfaces of the drywell shall be determined, during the shutdown fur each Type A containment leakage rate test, by a visual inspection of those surfaces.
This inspection shall be performed prior to the Type A containment leakage rate test to verify no apparent changes in appearance or other abnormal degradation.
j RIVER BEND - UNIT 1 3/4 6-22
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l UNITED STATES OF' AMERICA NUCLEAR REGULATORY. COMMISSION In the Matter of
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Gulf States Utilities Company
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Docket No. 50-458 Cajun Electric Power Cooperative
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(River Bdnd Station, Unit 1)
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EXEMPTION I.
The Gulf States Utilities Company, et al. (the licensee), is the holder of Facility Operating License No. NPF-47 which authorizes operation of the River Bend Station, Unit 1, at reactor core power levels not in excess of 2894 megawatts thermal.
The facility is a boiling water reactor located at the licensee's site in West Feliciana Parish, Louisiana.
The license provides, among other things, that the facility is subject to all rules, regulations and orders of the Commission now or hereafter in effect.
II.
Paragraphs III.C,3 and III.D.3 of Appendix J to 10 CFR Part 50, require
-that containment isolation valves, which may provide a pathway for' leakage of containment atmosphere, be tested on at least a 24-month frequency for compari-son with the limiting value of 0.6 L f r Type B and Type C tests.
a l
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The Gulf States Utilities Company proposed a one-time extension to this 24-month surveillance interval for conducting Type C tests on 5 containment-isolation valves.
The current testing interval is to be extended until the.
first refueling outage, which is scheduled to begin on September 15, 1987.
The extensions requested for leak testing these valves vary from 5 days to 29 days as shown in the following table:
EXTENSION (inch)
VALVE DAYS DESCRIPTION / SYSTEM SIZE a
4 G33*MOVF004 29 RWCU Pump Suction 6
l G33*MOVF054 29 RWCU Pump Discharge 4
C11*VF122 16 CRD Supply to Containment 2
SWP*MOV507A 05-SW Supply 12 J,
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SWP*V174 05 SW Supply 12 a
T The staff has found that approval of the proposed extension is warranted and that the proposed extension should be authorized by the granting of this L
one-time exemption so that the River Bend Station, Unit 1, may continue to operate until shutdown for the first refueling outage.
j 1
. q III.
The NRC has evaluated the licensee's b1 sis for requesting the extension in the surveillance interval and finds that not granting this exemption would require t'he licensee to shut down the plant on or about August 16, 1987 to conduct the testing.
The granting of this exemption is likely to result in a negligible reduction in containment integrity during the 5 to 29-day extension period.
In evaluating the changes to the Technical Specifications and the associated exemption, the staff reviewed the licensee's technical justifications for the requested extension.
The staff reviewed the licensee's position that a shutdown would be required to perform these tests.
The staff reviewed the previous leakage test results on the specific valves subject to the request for exemption and has found that there is ample margin between the leak rate values previously measured and the limiting values in Appendix J to accommodate any additional degradation likely to occur during the period of the extension.
The details of the above described' review are discussed in the enclosed Safety Evaluation.
Based on the c ove'information provided by the licensee and the staff's evaluation of the licensee's submittals, the NRC staff concludes that i
the licensee has provided an adequate basis for the conclusion that postponing the subject local leak rate tests until the first refueling outage is likely to have little effect on containment integrity.
The Commission's regulations in 10 CFR 50.12 state that the Commission will s
not consider granting an exemption unless special circumstances are present.
a
1 -
In its letter of March 10, 1987 as supplemented June 9 and July 8,15, and 30, 1987, the licensee addressed one of those special circumstances which is applicable to this request for exemption.
The licensee states that the special circumstances of 10 CFR 50.12 (a) (2) (v) are present in that the exemption would provide only temporary relief from the applicable regulation and became necessary because the preoperational testing was scheduled to be consistent with a projected fuel load date of April 1985.
The intent of the scheduling was to allow adequate time for the first cycle of operation so as to satisfy the 24-month Type B and C testing requirements of Technicai Specification 4.6.3.1.d at the first refueling outage.
However, the low power license was not issued until August 29, 1985 and commercial operation occurred in June 1986.
Only five valves require a surveillance extension out of a total population of 166 valves at River Bend Station that are associated with Technical Specification 4,6.3.1.d and Type C outleakage testing.
The exemption is temporary because these five valves will be tested during the refueling outage scheduled to begin September 15, 1987.
In addition, the licensee has committed to make a good faith effort to conduct these surveil-lances within the current frequency if an outage of sufficient length occurs.
On June 18, 1987, the River Bend Station entered an unscheduled outage.
The licensee stated that five surveillance tests, for which surveillance interval extensions had been requested, had been performed during this outage.
- However, the surveillance tests of the five valves for which an exemption was requested, were not performed because of considerations of ALARA, equipment availability, J
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and test duration vrgich wou d-have addedl a significant length of time to the a-
-s 4 oqta h.
The licensee stated that the' summer months are a time of high system de; ared and other sources of power in the licensee's system were not available p
such that' the River Bend Station could be maintained out of service for the extended period.
Therefore,jhestaff'concludedthatspecialcircumstancesof i
g 10 CFR 50.12(a)(2)(v) associated with this request fcr an exemption, have been demonstrated by the licende.
Accordingly, the NRC, staff finds that operation of R.'er Bend Station, Unit 1, during the proposed ext'ension period is acceptable.
herefora, the. staff finds that the proposed temporary exemption from i
10 CFR 50, Appendix'J, Paragraph'III.D.3 is acceptable.
IV.
Accordingly, the Commission has deterniined that, pursuant to 10 CFR 50.12, the proposed demptionis authorized by law, will not en' danger life or property or tnecommondefenseandsecurityandisotherbiseinthepublicinterest.
Therefore, the Commission hereby grants the exemption as follows:
^
"An exemption 1s granted from the requirement to conduct Type C testing on containment isolation valves at an interval no greater than 24 months asstatedin10CFR50,f.qpendixJ,ParagraphIII.D.3..
This exemption is granteO for the period spscified in the licensee's request for exemption dated March 10, 1987, supplemented July 8, 1987 (from current test deadline dates which begar;in August 16, 1987 until the first refueling outage which is scheduled to begin on Sercember 15,1937) and is only applicable to five valves in"the River Bend Station as listed in Section II. of this exemption."
i.
Pursuant to 10 CFR 51.32, the Commission has determined that the issuance a
of the exemption will have no significant impact on the environment (52 FR 28054).
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.6-A copy of the Commission's Safety Evaluation dated July 31,1987 related to
)
this action is available for public inspection at the Commission's Public i
Document Room, 1717 H Street, N.W. Washington, DC, and at the Government Documents
This Exemption is effective-on August 16, 1987 and is to expire at the start of the first refueling outage.
Dated at Bethesda, Maryland, this 31 day of July 1987.
FOR THE NUCLEAR REGULATORY COMMISSION Dennis M.1f 4
Crutchfield, 1 rector Division of Reactor P jects - III, IV, V and Special Projects i
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