ML20204J311

Discusses Request for NRC Approval of Revised Power Ascension Test Schedule,Per 870825,26 & 27 Discussions.Rev Required Temporary Deferral of IST 2.21.A.02, MSIV & IST 2.04.03, Turbine Trip W/Loss of Offsite..

ML20204J311
Person / Time
Site:	Beaver Valley
Issue date:	08/28/1987
From:	Carey J DUQUESNE LIGHT CO.
To:	NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
References
RTR-NUREG-1275 2NRC-7-197, TAC-63534, NUDOCS 8810250088
Download: ML20204J311 (2)

Text

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ttL*i" August 28, 1987 )

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U. S. Nuclear Regulatory Commission

%e N 3 Attn: Document Control Desk .

Washington, LC 20555 Roforence:

Beaver Valley Power Station, Unit No. 2 Docket No. 50-412 Beaver Valley Unit 2 Power Ascension Test Schedule Deviation IGOntlemen:

As per dis 7ussions between NRC Staff and K. D. Grada of Duquesne Light Company on August 25, 26 and 27, we requested NRC approval of aThis schedule.

revised power ascension test "Main Steam Isolation valve" orary deferral of IST 2.21.A.02 Power" and IST 2.04.03 "Turbine Trip with Loss of Offsite be sure at tests were originally scheduled to r at Lead". These K , formed at 30% power.

esca'. ate power to 50%, prior to performing these Our request to accomplishing the following tests, is for the purpore of two objectives:

Drains, system flows through the Heater Maximize Extraction Steam, Moisture Separator and Reheater Drains o

purpose of flushing those systems and Systems for the for future high power improving plant chemistry operations.

Provide a more effective clean out and inspection of the o condenser hotwell during a scheduled outage in main unit This will result in enhanced early September.

reliability for subsequent power operations.

Identify additional maintenance activities that have to ,

be performed on the balance of plant equipment during the ,

aforementioned outage. 1 days at 50% power ot' approximately five Following a period reduce power to our committed values and conduct i

l operation, we will We understand that this deviation is acceptable l 7ese two tests. brief duration of the elevated power condition and the l sed on the 1

% d11owing considerations:

• The Main Steam Isolation Valves have previously been l stroke tested and met their isolatior time criteria. l GS102500sa e70s2s KDR ADock0500g2 N f/M'Mn No: #[

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,No. 50-412, License No. NPF.73 No. 2 Power Ascensicn Test Schedule Deviation

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o The Emergency Diesei Generators nave previously .been tested and demonstrated their ability to re-energize the emorgency buses, o The Turbine Trip and Reactor Trip functions have bien demonstrated during unplanned trips with the unit connected to the grid on August 18 and August 25. Six sdditional reactor trips have occurred during pro-commercial operation.

o The positive aspects associated with operating at 50%

power 40 acccmplish the previously identified oojectives prior to our scheduled outage.

In addition to these discussions, the Project Manager expressed hio concerns over the number of plant trips that have occurred at Unit 2. Each of these events were discussed in detail as to their and actions. Whilo we recognize the

ccuses corrective continue to make every unocceptability of reactor trips and will effort in minimizing thom, we do not believe that our experience of is cignificantly differont than other plants during this phase cporation. Draft FURIG-1275 (March 1987) provides a comprehensive rcview of the startup experience of 16 plants. We note on page 12 the pre-commercial trip frequency, for the plants evaluated, 7^^

( *,le d between 4 and 23 with an average of 12.8 trips during this

-L- Je. Wo would also point out that only two Beaver Valley Unit 2 7 trips have occurred with the unit synchronized to the grid.

We believe that incraased ir.dustry attention must be given to the trips that occur with the unit on-line because o significant number of automatic actions occur under these conditions. This data base should be separated from reactor trips that occur in lower operating modas, which could only amount to an insertion of the' shutdown banks, with no other concurrent automatic actions. While we do not consider cny cha11onge on a safety system acceptable, on a risk assessment basis, the challenges that occur with the unit synchronized have a higher potential for sequential failures and should be separated from tho overall trip data base for this reason.

We appreciate the responsiveness of the staff on this schedulo change and believe it will provide boneficial results during cubsequent power operations.

Very tru yours, J. J. Carey Senior Vice President

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