IR 05000413/1986025

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Errata to NRC-Augmented Insp Team Repts 50-413/86-25 & 50-414/86-27,consisting of Pages 27 & 28 & Figures 2-6
ML20205A591
Person / Time
Site: Catawba  Duke Energy icon.png
Issue date: 08/04/1986
From:
NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II)
To:
Shared Package
ML20205A543 List:
References
50-413-86-25, 50-414-86-27, NUDOCS 8608110402
Download: ML20205A591 (7)


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Conclusion: Primary cause of the event was due to lack of knowledge of the design change that resulted in a procedure error which improperly set the S/G PORVs. Additionally, reluctance of the operators at the main control board to provide too much information to the crew at the ASPS for fear of invalidating the loss of control room test, combined with inadequate test termination criteria, caused the delay of nearly six minutes in terminating the test, even though the plant had reached safety injection initiatioa setpoint requirements. Once controls were transferred back to the control room, the operators were aware of, and anticipated the automatic initiation of safeti injection and the applicable emergency procedures were foll. owed.

(2) Finding: Deficient implementation of administrative procedures regarding labeling of components on the ASPS. This is another example of Violation 50-414/86-27-01.

Conclusion: Controllers for valves 2NV-294 and 2NV-309 were labeled improperly. This was done without the use of a procedure or work request.

' c.

Training Finding: Training was deficient in not adequately teaching the S/G PORV design change and the instrumentation and controls contained on the ASPS and the AFWPTCP. Appendix A to 10 CFR 55 requires that the ,~ licensee's requalification program include training so that each licensed operator and senior operator be cognizant of facility design changes.

This item will be identified as Violation 50-414/86-27-02, failure to provide adequate operator requalification training in accordance with Technical Specification 6.4.1.

,

Conclusion: The response of the licensed personnel during the event , was appropriate considering the identified deficiencies in training ' and procedures.

Previous NRC inspections and operator license examina-tion results are indicative of an overall satisfactory training program i administered at the Catawba station. The program wt.; deficient how-i ever, in not providing instruction of the shutdown panel instruments and controls and the PORV controller modifications.

l d.

Human Factors Deficiencies Finding: Although a human factors review of the S/G PORV design change was required, none was done.

Human engineering deficiencies resulting from the S/G PORV design were the major cause of the event.

The auxiliar) shutdown panels contain many other human engineering ' deficiencies, some of which induced operator errors during the loss of i control room test.

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- Conclusion: Most of the human engineering deficiencies had been identified by Duke Power in November 1982, and some were discovered as a result of the event. All of the identified deficiencies are scheduled for correction, with specific deficiencies scheduled to be corrected prior to restarting Unit 2.

e.

Analysis of Plant Response Finding: The plant did not violate any Technical Specification limits with regard to cooldown rate and shutdown margin.

The RCS was less than 10 F subcooled for 58 seconds and was saturated for 13 seconds.

At the time the RCA was subcooled, the licensee estimated that the net void in the RCS may have been as large as 500 cubic feet.

Conclusion: There were no adverse thermo-hydraulic or nuclear effects on the plant.

^ f.

Safety Injection Logic Finding: Manual transfer of control to the ASPS disabled automatic actuation of ESF functions and changed the operating status.of equipment.

(This item will be identified as Inspector Followup Item 50-414/86-27-03, Demonstrate feasibility of manually initiating safety injection from outside the control room.)

Conclusion: Blocking of ESF functions is acceptable provided the components can be manually placed in service to achieve and maintain shutdown. The licensee is required to prepare procedures for remote manual operation of the components blocked and must demonstrate the feasibility of manually initiating safety injection from outside the control room during the loss of control room test.

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