ML18153B851
| ML18153B851 | |
| Person / Time | |
|---|---|
| Site: | Surry  |
| Issue date: | 07/28/1989 |
| From: | Stewart W VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.) |
| To: | NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| References | |
| 89-082B, 89-82B, CAL, NUDOCS 8908140237 | |
| Download: ML18153B851 (5) | |
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VIRGINIA ELECTRIC.AND POWER COMPANY RICHMOND, VIRGINIA 23261 July 28, 1989.
United Stated Nuclear Regulatory Commission Region I I 101 Marietta Street, N.W.
Suite 2900 Gentlemen:
VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 OPERATIONAL READINESS ASSURANCE PROGRAM REQUEST FOR NRC CONCURRENCE Serial No.
89-0828 SPS/CMM Docket No.
50-281 License No.
DPR-37 Pursuant to our discussions and the technical meeting held at your Region II offices on July 20, 1989, the scope of the Unit 2 Operational Readiness Program is provided in Attachment 1.
Specifically, Attachment 1 provides the proposed Unit 2 plan for system walkdowns, electrical separation and logic testing.
The completion of the Unit 2 restart plans outlined herein will provide the basis for a final resolution of Items 6 and 7 of the March 9, 1989 Confirmation of Action Letter with respect to Unit 2 restart.
The information in this letter supersedes the Unit 2 program scope outlined in our letter dated July 7, 1989 (Serial No. 89-082A).
Should you have any questions, please contact us.
Very truly yours~
W. L. Stewart Senior Vice President - Power Attachment cc:
U. S. Nuclear Regulatory Commission Attn:
Document Control Desk Washington, D. C. 20555 Mr. W. E. Holland NRC Senior Resident Inspector Surry Power Station 8908J40237 890728 PDR ADOCK 05000281 p
PNU
ATTACHMENT 1 UNIT 2 OPERATIONAL READINESS ASSURANCE PROGRAM
UNIT 2 OPERATIONAL READINESS ASSURANCE PROGRAM System Walkdowns Objective To ensure that equipment is located in the proper train in accordance with the station drawings.
In addition, the walkdown process includes identification and evaluation of apparent discrepant conditions involving equipment structural arrangement, integrity and identification.
Unit 2 Walkdown Program The Unit 2 motor operated valves that may be required to operate for mitigating the consequences of an accident, as identified by a review of the emergency procedures, have been verified to be located in the proper train.
Common system walkdowns were completed prior to Unit 1 restart. Approximately 40% of the Unit 2 walkdowns are complete.
Prior to a Unit 2 restart, the systems in containment will be examined by walkdown.
Discrepancies identified to date and by the in-containment walkdowns will be dispositioned in accordance with Engineering Work Request (EWR)88-584.
The safety related systems outside of containment will be prioritized and walkdowns will be performed by system engineers under a new station procedure and completed by December 31, 1989.
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Electrical Separation Verification Testing Objective To ensure that train separation exi~ts for safeguards equipment with respect to its source ~f electrical power.
Unit 2 Testing The 4160/480V Switchgear and 480V MCCs, 120 VAC vital bus panels and 125 VDC panels will not be completely de-energized during Unit 2 testing.
De-energizing the 4160/480V buses is not required based on previous bus outages using approved procedures.
These procedures are based on and validate the electrical one line diagrams which show that train separation exists.
With both units in cold shutdown, electrical separation verification testing was more readily achievable.
With Unit 1 at power, the unit would be placed in various Technical Specification Limiting Conditions for Operation such as the loss of auxiliary feedwater cross connect capability and one train of heat tracing which is powered from Unit 2 J Bus.
The basic testing process is outlined below:
For 120 VfJ.C vital bus panels, each breaker will be cycled on/off to verify the loads.
For 125 VDC panels, the breakers will not be cycled.
An initial DC voltage will be taken at each test point.
The battery powering that DC bus will then be placed on an equalizing charge and the voltage measured to ensure an appropriate increase has occurred at each test point.
Opposite train DC bus voltage and ESF circuits will be monitored to ensure voltage does not change.
The Unit 2 test scope will only be performed on the 11 8 11 train (2J) this outage.
The research phase of a test procedure for 11A 11 train (2H) will be completed prior to Unit startup and testing will be performed at the next refueling outage.
Drawing changes identified during the test procedure research will be completed 90 days after Unit 2 startup.
Pump and valve breaker power supply verification testing will be conducted on a representative sample selected from both 11A 11 and 11 8 11 trains.
The sample will consist of 60 components.
Zero discrepancies within the sample will provide a 95% confidence level that less than 5% discrepancies exist for the population.
The sample size will be increased if discrepancies are found.
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Logic Testing Objective The purpose of the these Special Tests (STs) is to functionally test the operation of Safeguards equipment after the manual injection of an Engineered Safeguards Feature (ESF) signal (Hi Hi CLS, Hi CLS, SI) and bus' undervoltage (UV) signal.
The UV signal is injected at different times to ensure that the load sequencing modification operates properly and does not affect the original design of the safeguards equipment.
Unit 2 ESF Testing
- ESF Actuation With Instantaneous Bus UV The test consists of an ESF actuation with an instantaneous bus undervoltage.
During this test the Emergency Diesel Generator (EOG) starts and picks up the emergency bus load.
Pump breakers are placed in the test position and therefore do not actually run.
- ESF Actuation With Five Minute UV Delay The test consists of an ESF actuation with an UV signal five minutes later.
During this test, the pumps are run in the recirculation mode except for the Inside Recirculation Spray Pumps.
The EOG starts and picks up the emergency bus load after the UV signal.
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