IR 05000322/1979015
| ML19256G328 | |
| Person / Time | |
|---|---|
| Site: | Shoreham File:Long Island Lighting Company icon.png |
| Issue date: | 11/07/1979 |
| From: | Caphton D, Nicholas H NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
| To: | |
| Shared Package | |
| ML19256G327 | List: |
| References | |
| 50-322-79-15, NUDOCS 7912310058 | |
| Download: ML19256G328 (9) | |
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U.S. NUCLEAR REGULATORY COMMISSION OFFICE OF INSPECTION AND ENFORCEMENT Region I Report No. 50-322/79-15 Docket No. 50-322 Category B'
License No. CPPR-95 Priority
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Licensee:
Long Island Lighting Company 175 East Old Country Road Hicksville, New York 11801 Facility Name:
Shoreham Nuclear Power Station, Unit 1 Inspection at:
Shoreham, New York Inspection conducted:
September 21-22, 1979
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Inspectors:
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H. H. Nicholas, Reactor Inspector datepign(d date signed
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da e signed Approved by:
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D. L. Cephton, Chief, Nuclear Support Section date signed No. 1, RO&NS Branch Inspection Summary:
Inspection on September 21-22, 1979 (Report No. 50-322/79-15)
Areas Inspected:
Routine, announced inspection to witness the reactor pressure vessel and main steam line hydrostatic test; plant tours of containment, reactor building, control room, turbine building, and, diesel generator rooms; and, followup on previous inspection items.
The inspection involved 12 inspector-hours onsite by one regional based inspector.
Results:
No items of noncompliance were identified.
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DETAILS 1.
Persons Contacted Long Island Lighting Company
- Mr. T. Joos, QA Engineer Mr. L. Lewin, Assistant Startup Manager Mr. A. Muller, QC Engineer Mr. J. Navarro, Project Manager
- Mr. G. Nicholas, QA Section Supervisor Mr. J. Taylor, Startup Manager Mr. A. Wofford, Vice President Stone and Webster Corporation Mr. J. Baker, Lead Advisory Engineer General Electric Corporation Mr. M. Davis, Test Engineer
- Mr. R. Moody, Lead Test Director Mr. P. Quinn, Test Engineer Mr. P. Ray, Test Engineer
- Mr. J. Riley, Lead Startup Engineer Courter and Company Mr. T. Hamlin, Hydro Test Coordinator
- Mr. J. Schmit, Superintendent SQA Hartford Steam Boiler Mr. D. Baldonado, ANI Inspector Mr. G. Cocuzzo, Lead ANI Inspector Mr. R. Cruz, ANI Inspector Mr. H. Evans, ANI Inspector Mr. C. Lizotte, ANI Inspector Mr. W. Meyer, ANI Inspector Mr. A. Olivares, ANI Inspector Mr. S. Yuan, ANI Inspector The inspector also interviewed other licensee personnel during the course of the inspection.
- denotes those present at the exit interview.
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2.
Status of Previous Inspection Items (Closed) Unresolved Item (322/79-14-01):
Diesel engines external moving control linkages exposed and uncovered.
The inspector observed that all precision moving parts had been cleaned and covered or taped, so as to prevent accumulation of dirt, construction debris and foreign substances from adhering to the polished surfaced.
This item is closed.
3.
Reactor Pressure Vessel and Main Steam Line Hydrostatic Test References:
S&W Test Pressure Diagrams:
TPM-20A and B, RHR System
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TPM-21A, Standby Liquid Control System
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TPM-22A, RCIC System
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TPM-23A, Core Spray System
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TPM-25A, HPCI System
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TPM-26A and B, Reactor Recirculation System
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TPM-27A, CRD System
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TPM-28C, Sample System
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TPM-29A and B, Main Steam System
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TPM-32A, Feedwater System
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TPM-45A, Misc. Drains - Secondary Plant
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TPM 48A and B, Nuclear Boiler Instrumentation
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TPM-24A, Reactor Water Cleanup System
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MFSK Valve Diagrams MFSK 20A and B, RHR System
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MFSK 21A, Standby Liquid Control System
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MFSK 22A, RCIC System
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MFSK 23A, Core Spray System
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MFSK 24A, Reactor Water Cleanup System
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MFSK 25A, HPCI System
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MFSK 26A and B, Reactor Recirculation System
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MFSK 27A, CRD System
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MFSK 28C, Sample System
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MFSK 29A and B, Main Steam System
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MFSK 32A, Feedwater Syster.
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MFSK 45A, Misc. Drains - Secondary Plant
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MFSK 46A, Radwaste Equipment Drains
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MFSK 48A and B, Nuclear Boiler Instrumentation
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S&W Specification SHI-412, Pressure Testing of Installed Piping.
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Courter & Company Generic Procedure PT 100, Pressure Testing of Installed
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Systems.
S&W CIP 6.7, Pressure Testing of Installed Systems.
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LILC0 Reactor Vessel Instruction Manual, CE Book No. 3067.
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Station Procedure SP23.106.01, CRD System.
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Proposed Technical Specifications, 3/4.4.6.
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Final Safety Analysis Report, Section 5.2.
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Courter & Company Quality Procedures:
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QAP 8.2, Pressure Testing QAP 9.1, Control of Measuring and Test Equipment.
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Detailed Test Procedure CS 136.001, Reactor Pressure Vessel and Main Steam Line Hydrostatic Test.
a.
Introduction The object of this test is to verify the integrity and leak
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tightness of the reactor pressure vessel, connecting piping welds, and the main steam lines by performance of a hydrostatic test at 125 percent of design pressure (1562.5 psig) measured at the top of the vessel.
The hydrostatic test boundaries consist of the following as
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defined by the test pressure diagrams:
(1) Reactor pressure vessel and recirculation system; (2) Main steam lines to the turbine stop valves and bypass
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valves; (3) Feedwater lines to first manual shut-off valve; (4) HPCI, RCIC, SBLC, RWCU, and core spray system, to the first isolation valve; (5)
Instrument and sample lines within the pressure test boundary to last isolation valve before the instrument; and, (6) RHR shutdown cooling to the outboard isolation valve.
The hydrostatic test consisted of filling the reactor pressure
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vessel and all associated piping to the first valve including the main steam piping to the turbine stop valves and the bypass valves.
(1) An RHR loop with RHR pumps running, supplied heatup of coolant.
(2) With reactor coolant temperature above minimum for boltup and tensioning of RPV head, and above minimum for pressuri-zation, the hydrostatic test was begun with pressure plateaus
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of 50, 75, 500, 1000, and final hydrostatic test pressure at 1565 psig for 10 minutes.
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(3) After completion of 1565 psig hold, pressure was reduced to 1250 psig and held until leak inspection of all welds and mechanical fittings within the test boundary was performed.
b.
Observations Prior to the start of the test, the inspector verified the following:
Valve positions were checked;
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Latest drawing revisions were used in conjunction with the valve
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lineup procedures; Latest boundary diagrams were in use;
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A calibrated, serialized, and dated pressure gage of proper range
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had been installed and designated as the " Official Gage" and that a second similar gage had been installed as a backup; Overpressure protection was provided by an installed, sealed,
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pressure-range and capacity stamped, serialized relief valve with a second installed relief valve as a backup; Reactor pressure vessel and main steam line coolant was above the
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specified minimum temperature; Required supporting systems were functional;
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All welded joints and mechanical connections wert. uncovered;
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All temporary instrumentation had been installed and calibrated;
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and, Communications had been established between all ttations, central
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control point, and all inspection teams.
c.
Crew Performance The inspector observed the following:
The hydro procedure with the latest revision was available and in
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use by crew members; The minimum crew requirements had been met;
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Briefings had been conducted with the crew and the inspection
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teams; Adequate " dry runs" were conducted by inspection teams;
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All test prerequisites were met;
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Appropriate plant systems, as needed, were in service;
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Special test equipment and instrumentation required by the procedure
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was calibrateJ, in service and manned by test personnel; Testing was being performed as required by the procedure;
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Crew actions appeared to be correct and timely during the perfor-
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mance of the test; and, All data was collected for final analysis, by the cognizant test
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personnel.
d.
Test Witnessing By direct observation, the inspector witnessed the following:
The manning and conduct of test at the charging area, temperature
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monitoring area, and upper reactor pressure vessel head area; Water sampling and results for water quality;
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Reactor pressure vessel temperature greater than 1400F;
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System pressure at 50 psig and temperature at 1800 ;
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System pressure at 75 psig and temperature at 1800F;
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System pressure at 500 psig and temperature at 1790F;
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System pressure at 1000 psig and temperature at 1790F;
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Reactor pressure vessel flanges and upper head area, temperature
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monitoring panel, and charging pump area, at 1000 psig and 1790F; Attaining and holding 1565 psig for 10 minutes at the official
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test gage on the reactor pressure vessel upper head; 1660 310
Depressurizing to 1250 psig and holding for detailed inspection
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of all welds and mechanical joints; All assembled inspection teams passing into containment and to
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their respective areas of inspection; Accompanying an inspection team into containment and inspecting
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welds on reactor pressure vessel nozzles, nuclear boiler piping, and core spray piping; and, Allowable heatup rates and pressure increase and decrease rates
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were observed and within limits.
The inspector made independent measurements and calculations in the areas of temperature, pressure, time, and rates of change in parameters.
Test results observed by the inspector indicated that acceptance criteria had been met.
Findings The inspector established by records review, by independent calculations and measurements, by direct observations, and by test witnessing, that testing was conducted in accordance with approved procedures.
The inspector independently verified the acceptability o'f the test results, and evaluated the performance of the licensee personnel involved in the test performance.
No discrepancies were noted and no items of noncompliance were identified.
4.
Plant Tours The inspector made tours of the facility during the course of the inspection including containment drywell, reactor building, turbine building, control room, and diesel generator rooms.
The inspector visually observed and examined the staging, platfonns, ladders, and lighting around all piping, penetration welds, valves, reactor pressure vessel, and temporary connections pertinent to the reactor pressure vessel and main steam line hydrostatic test.
In all areas inspected, observation also included housekeeping, cleanliness controls, storage and protection of components, piping and systems.
No discrepancies were noted and no items of noncompliance were identified.
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5.
Exit Interview At the conclusion of the site inspection on September 22, 1979, an exit meeting was conducted with the licensee's senior site representatives (denotedinParagraph1). The findings were identified and the unresolved item was discussed.
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