IR 05000206/1981029
| ML20010J385 | |
| Person / Time | |
|---|---|
| Site: | San Onofre  |
| Issue date: | 09/15/1981 |
| From: | Chaffee A, Zwetzig G NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV) |
| To: | |
| Shared Package | |
| ML20010J384 | List: |
| References | |
| RTR-NUREG-0737, RTR-NUREG-737, TASK-2.E.4.1, TASK-2.E.4.2, TASK-2.K.3.09, TASK-TM 50-206-81-29, IEB-80-04, IEB-80-4, IEB-81-03, IEB-81-3, NUDOCS 8109300402 | |
| Download: ML20010J385 (7) | |
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y U. S. NUCLEAR REGUL\\ TORY COMMISSION OFFICE OF INSPECTION AND ENFORCEMENT I.1
REGION V
.g Report No. R1_ ')Q Docket No. 50-206 DPR-13 ticense 30, Safeguards Group Licensee:
Southern California Edison Company F.
V.
DOX OUU 2244 Walnut Grove Avenue
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Rosemead, California 91770 Facility Nace:
San Onofre Unit 1 Inspection at:
San Onofre, California Aygust 17-21, 1981 Inspection conducte :
Inspectors: N[
g[/f F/
I.'Citafffe'e,ReactorInspector Date Signed Date Signed M
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Date Signed bApprovedby:
4. 6. 2 *N 9 /tr' 71
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e G.B.Zwet/g',Chfef Date Signed
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Reactor Projects Section 1
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- Summary:
Inspection on August 17-21, 1981 (Report No. 50-206/81-29)
Areas Inspected: Routine, unannounced inspection of IE Bulletins, fire protection modifications and TMI modifications. This inspe~ction involved 32 inspector-hours onsite by one NRC inspector.
Results: No items of noncompliance or deviations were identified, i
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RV Form 219 (2)
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DETAILS 1.
Persons Contacte_d
- J. Curran, Manager, Quality Assurance
- H. Ray, Station Manager
- H. Morgar,. Assistant Station Manager, Operations
- F. Briggs, Compliance Engineer
- J. Reeder, Supervisor of Plant Coordination, Unit 1
- R. Santosuosso, Assis ant Stat'on Manager, Maintenance
- E. Gault, Clerk-Typist
- J. Haynes, Manager, Nuclear Operations
- B. Kate, Assistant Station Manager, Technical
- G. Mcdonald, QA/QC Supervisor
- J. Dunn, Project Quality Assurance Supervisor
- Denotes those persons who attended the exit interview.
Also present at the exit interview was the NRC Senior Resident Inspector, L. Miller.
2.
Follow-up on IE Bulletins a.
IE Bulletin 80-06 (Engineered Safety' Feature (ESF) Reset Controls)
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(0 pen)
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N The inspector reviewed the licensee's letter dated August 6 1981, to the Office of Inspection and Enforcement, Region V.
This letter indicated that all-valves responded properly except MOV 1100 B, C: and D.
To correct this condition, the licensee has schec" led modifications to be completed during the next refueling outage.
in the interim, the licensee has established administrative controis to assure proper operation of MOV 1100 B, C and D during ESF reset. These controls are discussed in the licensee's submittal of August 6, 1981. This. item will be reviewed further after completion of NRC-approved modifications.
b.
IE Bulletin 80-04 Analysis of a PWR Main Steam Line Break With
"ontinued Feedwater Addition -(Closed [
(1) Licensee Corrective Actions (a) Reduction in main feedwater isolation respnse time:
This was accomplished by addition of a high containment pressure signal (with a setpoint of 1.4 psig) which actuates engineered safety features (ESF). When ESF is actuated, feedwater from the main feed pumps is isolated.
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-2-(b) Verificatien of min steam piping integrity inside containment: This was accomplished by radiography 1ng main steam piping welds inside containment.
(2)
Inspecter Review The inspector reviewed Instrument and Test Procedure S01-II-1.80, Rev. O, dated May 29,1981, " Monthly Containment Isolation Channel Test", which was conducted on August 13,1981.
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i Based on this review and discussions with licensee personnel, the inspector concluded the following:
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(a) ESF is h w actuated by a high containment pressure of 1.4 psig, which results in isolation of the main feedwater supply to the steam generators.
(b) The licensee appears to have perfomed radiographs on all main steam line welds inside containment.
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Thus, the licensee appears to have completed the corrective actions addressed in his response dated March 6,1981, to this bulletin.
This item is closed.
c.
IE Bulletin 81-037 Flow Blockage of Cooling Water to Safety System Components by Corb4cula Sp.'(Asiatic Clam) and Mytilus Sp. (Mussel))
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'Open)
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The inspector reviewed.the licensee's submittal dated June 4, 1981, and Licensee Event Report '(LER) 81-09 submitted July 27,
' 1981.
Based on the above review and discussion with licensee personnel,' the inspector concluded that the licensee's response
s to IE Bulletin 81-03 appears. adequate except for their provisions for addressing long term shutdown (as revealed by LER 81-09).
The licensee has committed to include a method for dealing with the problem encountered in LER 81-09 in an appr.)priate procedure by September 15, 1981. This _ item will be follosed up at a future inspection.
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3.
Follow-up on TMI Items
a.
Item II.E.4.2 (5b), Reduced Setpoint for Initiating Containment
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Isolation on High Containment Pressure.
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The inspector reviewed Instrument and Test Procedure S01-II-1.80,
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Rev. O, dated May 29,1981, " Monthly Containment Isolation Channel Test", which was conducted on August 13, 1981.
Th!s review revealed that the pressure set point had been reduced te :. 4 psig as required. This item is cic3ed.
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Item II.E.4.2(7), Containment Purge and Vent Valve Isolation on High Radiation Signal This TMI item requires that the containment purge and vent valves isolate on a high radiation signal. This control fonction is required to be installed prior to July 1,1981, by NUREG 0737.
The inspector reviewed the following documentation:
(1) Surveillance Instruction S01-12.2-2, Rev. 1, dated June 3, 1981, " Operational Radiation Monitoring System Test," which was conducted on August 7, 1981.
(2) Station Order S01-A-112, Rev. 5, dated August 28, 1980,
" Station Quality Assurance Program."
(3) Emergency Operating Instruction S01-1.3-1, Rev. O, dated June 28,1981, "Hiah Radiation Operational Radiatio. Monitoring System (ORMS)."
Based on the above review and di~;us:, ions with licensee personnel the inspector determined the h owing:
(1) Containment purge valves POV-9 and POV-10 and containment
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vent valves CV-10 and CV-116 will automatically close (if
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open) when a high radiation alarm is received on channel
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R-1212 of the ORMS.
(2) Channel R-1212 of the ORMS normally monitors containment sphere gas activity ( and the alarm is set at twice the nornal inservice reading 3000 cpm). This channel can also sample the stack gas activity when the normal stack gas channel l
R-1214 is inoperative.
In this case, the high alarm is set at 20,000 cpm.
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(3) The hardware for this control function apparently is not fully qualified. The licensee has stated in his submittal dated June 23, 1980, that the ORP5 is located outside containment in the ventilation equipment building. Thus, it will remain at ambient conditions following an accident and post-accident radiation doses will be insignificant. The licensee, therefore, states this equipment is environmentally qualified based on operating experience. The licensee, however, did not address seismic qualifications in his submittal and, based on document review and discussions with licensee personnel, it appears that this equipment is not seismically qualified.
The qualification adequacy of this system is being evaluated by the Systematic Evaluation Program (Topic VI-4, Containment Isolation System).
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Based on the foregoing, it appears that the licensee meets the
present requirements of NUREG 0737 in that the purge and vent valves will shut on a high radiation signal. However, the qualification of this system is still under review by the Systematic Evaluation Program Topic VI-4.
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This item is closed.
c.
Item II.E.4.1, Long Term Accident Hydrogen Control
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term control of hyd ogen released inside containment following an accident. The (,uidance allows either the use of installed safety grade hydrogen recombiners or dedicated redundant penetration systems to allow either venting of hydrogen gas or installation of external recombiners.
The inspector reviewed the following doctanents pertaining to this matter:
D. M. Crutchfield (NRR) letter to P. Dietch (SCE) dated
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May 2, 1980.
NUPEG 0578, July 1979, Sec. 2.1.5.
NUREG 0737, November 1980, Sec. II.E.4.1.
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Operating Instruction S01-5-11, Rev. O, April 24, 1981,
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" Post Accident Hydrogen Gas Control."
San Onofre Nuclear Generating Station Unit 1 Design Criteria Manual, Three Mile Island Project, including Change 8, April 6,1981.
Design Change 80-04, " Safety and Environmental Analyses l
For The Installation of Containment Hydrogen Recombiners,"
November 20, 1980.
Proposed Procedure Change Notice (PCN) to Procedure 501-5-11.
Based on review of the above documents and discunions with licensee
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personnel, the~ inspector concluded the licensee has met the requirements
of this item as follows:
(1) The licensee has written ' procedures to utilize the existing vent, purge, instrument air, and radiation monitoring systems
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to provide a single-failure proof penetration system to i
vent hydregen.
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l (2) The licensee has installed two redundant safety grade hydrogen
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(3) Procedures for the above systems have been developed and
implemented.
It is noted that in reviewing these procedures, the inspector identified some inconsistencies in Procedure S01-5-11, " Post Accident Hydrogen Gas Control." These discrepancies were resolved satisfactorily with the issuance of a PCN on August 21, 1981, to C.;s procedure.
This item is closed.
d.
Item II.K.3.9, Proportional Integral Derivative Controller Modification (open)
The licensee reported in Licensee Event Report (LER) 81-13 that the vendor recommendation to turn "off" the derivative time constant to the Propartional Integral Derivative (PID) Controller to Power
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Operated Relief Valve (PORV) 545 produced increased sensitivity to pressure. increases rather than a reduced sensitivity.
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This is opposite to the intent of Item II.K.3.9 of NUREG 0737.
Accordingly, the licensee has implemented interim administrative controls to fulfill the intent of this item until permanent modifications j
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can be installed. The licensee has committed to complete these modifications during the steam generator inspection outage scheduled
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for six effective full power months of operation. This matter-
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will be followed un after completion of the revised modifications.
4.
Follow-up on Outstanding Item (80-18-02$ Fire Protectior. Modifications Required Prior To Start-Up On June 15. L981 (Closed)
Th6 inspector reviewed the following documents:
Start-Up to Operations Turnover Package Number 4 (SU-T/0 #4)
a.
e.nd SU-T/0 #h These two turnover packages cover the inuallation status of the two types of fire detectors for the lube oil reservoir
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area which are required by Item 3.11 (5) of the Fire Protection l
Safety Evaluation Report (FPSER), dated July 19, 1979.
b.
SU-T/0 #57500: This package' addresses the installation status of insulation on the North Turbine Wall to insure a one-hour fire barrier rating for this wall, as required by Item 3.1.11(c)
of the FPSER.
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SU-T/0 #80125: This package addresses the completion of installation of fire protection curbing around the charging pumps, the Hydrogen Seal Oil Unit and the Engine Driven Screen W sh Pump.
This curbing a
Was required by items 3.1.15(b), 3.1.15(c), and 3.1.15(j) of the FPSER.
d.
SU-T/0 #30: This package deals with the completion of installation of a three-hour rated fire door in the 480 volt room facing the station service transformers, as required by Item 3.1.15(1) of the FPSER.
Based on review cf the above documents, discussion with licensee personnel, and visual observation of the North Turbine Wall, the inspector concluded that the above items appear to have been completed satisfactorily prior to startup on June 15, 1981. This item is closed.
5.
Exit Interview The inspector met with licensee representatives (denoted in Paragraph 1)
on August 21, 1981. The results of the inspection were discussed
and no formal committments were requested.
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