Text

Monthly Operating Rept for June 1987
	ML20237L636
Person / Time
Site:	Vogtle
Issue date:	06/30/1987
From:	Dilworth S; GEORGIA POWER CO.
To:	;
Shared Package
ML20237L607	List: ML20237L603; ML20237L636;
References
	NUDOCS 8708200288
	Download: ML20237L636 (6)
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l 08ERATING DATA PEPORT UNIT: 906TLE 1 LOC >ET'NO. 50-424 OATE: 67-Jul-87 ]

COMPLETED BY: 3. C. DILWORTH- !

TELEPHONE: (404) 724 8114 x3a70 OPE' RATING SrATUS .

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1. UNIT NAME: A. W,'V0GTLE UNIT 1

2. REPORT PERIOD: ' .Jun-07

3. LICENSED THERMAL POWER (MWt):

3411

4. NAMEPLATE PATING (GROSS MWe): -1160

-5. DESIGN ELECTRICAL RATING (NET MWel 1101

6. MA11 MUM DEFENDABLE CAPACITY (GROSS MWel '.124

7. MAXIMUM DEPEN 0ABLE CAPACITY (NET MWe): 1069 j

'8. [F. CHANGES OCCUR IN CAPAC[TY RATINGS J (ITEMS 3 THROUGH 7)'SINCE LAST REPORT, GIVE REASONS: NO CHANGES

9. POWER LEVEL TO WHICH RESTRICTED. [F ANY (NET MWe): NO RESTR!CTIONS

10. REASONS FOR RESTRICTION, IF ANY: NA

.THIS MONTH' .Y R . TO DATE

11. HOURS IN REPORTING PERIOD: 720

.CUMULAT!VE .l 720 720 ;

12. NUMBER OF HOURS REACTOR WAS CRIT! CAL: 325.3 325.3 325.3 13.~ REACTOR RESERVE SHUTDOWN HOURS: l NA NA .NA

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.14. HOURS GENERATOR ON-LINE: 276.4 276.4 276.4 I

'15, UNIT RESERVE SHUTDOWN HOUR $r' NA NA NA 16, 6AOSS THERMAL-ENER6V GENERATED (MWHl: 759746 759746 759746 -!

(7 CROSS ELECTRICAL. ENERGY OENERATED (MWHis 240180 240100 240100

18. NET ELECTRICAL ENER6Y GENERATED (MWH): 202150' 20:150 202150

19. REACTOR SERVICE FACTOR: 45.2% 45.2% 45.2% l

20. REACTOR AVAILABILITY FACTOR: 45.2% 45.2% 45.2%

21. UNIT SERVICE FACTOR: 18.4% *B.4% 38.4%

22. UNIT AVAILABILITY FACTOR: .

38.4% 30.4% 38.4% ,

23. UNtf CAPACITY FACTOR (USINB MDC NET): 26.3% 26.3% 26.3% :l

'24. UN[T CAPACITY FACTOR (USING DER NET): 25.5% 25.5% 25.5% l

25. UNIT FORCED OUTAGE RATE.: 61.6% 61.6% 61.6% i 26.-SHUTDCWNS SCHIDULED OVER THE NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH):

1 TYPE ' MAINTENANCE AND TESTING. DATE: OCTOBER 2, 1987 e. DURATION 10 DAYS

27. IF SHUTDOWN AT END OF REPORT PERIOD, EST! MATED DATE OF STARTUP: N/A I l28. UNITS IN. TEST STATUS (-PRIOR TO COMMERCIAL OPERATION): N/A t

e TENTATIVE DATE.

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. 70GTLE I i, l S0WER LEVEL COCh ET NO. 50 424 l DATE: 07-Jul-87 COMPLETED Bf: 5. C. DILWORTH TELE # HONE: (404) 724-8114 v3870 D A 'f Net NW .

1 ........ 1109 +

2 ......... 1105

I ....... 735 4 ......... 0 5.. ...... 0 6 .. . .... 0 7 ......... 9 0 .. ..... 0 0 ......... O to .. ...... 0 11 ......... 0 12 .... .... 0 13 ......... 196 14 ..... ... 433 15 ......... 0 16 ......... 0 17 ......... 0 10 ........ 0 19 ......... 0 20 ....... . 0 21 ......... 22 -

22 ......... 310 !

23 ......... 735 24 ......... 0 25 ......... 30 26 ......... 019 ,

27 ......... 1136

20 ......... 1110

29 ......... 1119 +

30 ......... 1113

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NOTE: Days marked with an asterisk (*) reflect power greater than 100%. Items 6 and 7 on page E-l are theoretical and will be corrected after sufficient operating data has been obtained.

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VNIT SHUTDOWNS AND POWER AEDUCTIONS DOCKET NO. 30-4I4 OATE: 07-JUL-97 UN!'T NAMER V0GTLE 1 COMPLETED Bf S.C. CILWCstw TELEPHONL (404) 724-0119 (3070) {

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GEPORT FONTH JUNE 1997 .

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F FORCED REASON: METHOD: EVENTS REPORTED INVOLVE St SCHEDULED A-EDUIPMENT FAILURE (EXPLA!N) 1 - MANUAL A GREATER THAN 20%

B-MAINTENANCE OR TEST 2 - MANUAL SCRAM REDUCTION IN AVERAGE l C-REFUELING 3 - AUTO. SCRAM OAILY POWER LEVEL FOR ,

D-REGULATORY RESTRICTION 4 - CONTINUATION? THE PRECEEDING 24 HOURS, !

E-OPERATOR TRAINING & LICEN'SE 5 - LOAD REDUCTION l F-ADMINISTRATIVE 9 - OTHER (EXPLAIN) l G-OPERATIONAL ERR 04 (EXPLA[N)

LER NUMBER TO BE ASSIGNED l H-0THER (EXPLAIN) l l

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. AITACIHiNI

, i ad . OPERATING DATA REPORT V0GTLE-1 JUNE 1987 A - Cause/B - Corrective Action to Prevent Reoccurrence ;

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1. A. h root cause for the relay actuation as due to a-

'Jteper. h transformers ' jumper was installed on Phase A & B current for shipment and were not removed during startup. h jtmper should have been removed during the- i performance of the Construction Acceptance Test (CAT) !

procedure (CAT-E-02), which a caution note concerning current transformer (pivvided CT) grounds.

B. The shipping grounds located on the current _ transfomer I (CT) were removed and the construction test procedure !

(CAT-E-02) was reviewed for adequacy. On previous !

revisions of the procedure there had been a note concerning the GT gi; rounds. On' May 11, 1987, the procedure had been revised to include a sign-off step to ensure that only one ground exists in the CI circuit.

This was considered adequate so no further changes were i considered necessary. j

2. A.' h imediate cause of the reactor trip as due to Source i Range High Neutron Flux. h root cause of the high flux trip was due to Reactor Operator (R.O.) error. h R.O. !

was not attentive to the reactor startup, did not recognize the reactor was critical when bank C ms at 99 1 steps, and relied upon a trainee who had never been involved in an actual plant startup. 4 B. h R.O. was recoved from any licensed duties until i adequate retraining ' had been performed as determined by i the Operations Manager, p

The R.O. and the Shift Supervisor (SS) have received j

additional sinulator training for reactor plant startups. .

An Inverse Count Rate Ratio plot shall be required for each reactor plant starrup.

h procedure 14940-1, " Estimated Critical Condition Calcu:.ation", and the Plant Technical Data Book have been reviewed by Reactor Engineering and revised.

3. A. N imediate cause of the event was the hi-hi water level in Steam Generator No. 2. The root cause of the event was personnel error, h trip was caused by the Shift Supervisor who opened the Steam Generator No. 2 1

MFRV too far. A contributing cause of the event was a l procedure deficiency in that reactor power was too high l for transferring from the BFRVs to MPRVs. Another !

contributing cause was that the No. 3 BMtV seemed to l oscillate. '

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5 B. A second operstor to support the Steam Gener tor

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operation has been assigned to shift during plant startup operation for transferring from BFRVs to MFRVs.

h Unit Operating procedure (UDP), 12004-1, has been ' l l revised to require a low reactor. power level (15%) when transferring from BEV to MFRV.

I &' C investigated control systems and limits for BFRVs and found B N s to function properly. W croka for No. i 2 MFRV was also checked and found to function properly. _

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l 4. A. The reactor trip was caused by a. low low stean generator i level condition, h "A" MFP discharge check valve l (1-1305-U4-502) failed and the breaker feeding the !

discharge actor operated valve 00V) tripped while in the open position. {

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h mot cause for the failure of 1-1305-U4-052 has been {

attributed to inadequate hinge pin design for this particular undel and size valve. This valve is a Pacific 20 inch Tilting Disc meck Valve, Model 58809-7-WE(120).

B. To prevent recurrence of the check valve' failure, j redesigned e pins have been installed for the "A" &

"B" WP disc e check valves, 1-1305-U4-052 and 1-1305-U4-060. The new design has the following features: i

1. h pin head diameter has been enlarged from 2" to 3" l to provide greater bearing area on the, axial stop. '

2. h width of the pinhead has been increased to minimize the amount of axial covement, thus assuring that the antirotation flat remains engaged with the disc.

3. h pin head exterior matin 8 surface is fully round, i.e., the antirotation flat is only partial width, to preclude bypassing of the axial stop.

4, The pin has been 1 thened to ensure full engagement through the disc and er asserbly, i

5. A. h root cause of the reactor trip is vendor fabrication error. h error was the result of ne installing a ferrule on the hydraulic fluid tubing connection which failed. Although the . connection may have had some preliminary leakage, it was enclosed in guard piping which prevenced early detection. Only after several-hundred hours of ptrap turbins operation did the connection work loose to the point the major leak occurred.

B. The faulty hydraulic tubing connection was replaced. All similar tubing connections on each of the two W puup turbine skids were inspected to ensure their integrity.

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Ab ;0n m[,e 2d,. 1987, at 0942 CDT, while in Mode 3 and with

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,7k*e. (/' , shutdown (rap _ banhytrtially withdrawn,'. the treactor was y

of - 3 '~ ..h'O 'Ta maiul&

' 1" Specification tripped it:Aetwgly :with the require!ments ' of R '.1.3.3. his menud trip was ;

initiktad . after ' receipt, p of an ,"RPI Urumt Alam" h,

o annunciator. on indicated failure off ital'! Rod v

Position Indicator (DRPI)' for shutdown ank "B BodlG 3.

After was' theormedttrips;dworer, h no failures or4 thorough less could checkout be

',Jdof iden ified., success reactor. startup +i was car;1std jSiw.quently a ca June 21, 1987, with no CRPI failure. ,

q~. On June 25,187, the Unit was again in Mode 3 and the M shutdown rod banks were being withdrawn when another DRPI ?

? failure ' occurred for shutdown Rod G-3; 2e rotac.too was 3 tripped at 0119 - CUI. F;O or g .sthis-.

,therefore trip, .a detectormanually /cacoder card in the' " DF21 Data Cabinet was disco @ered to have failed. . ~

s cdrd was W$

O Ythen replaced arid athsequent testing daaonstrated that -

proper;indicatior.f<as. been restored for Rod'G-3.

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'. , f. e he dailed card,"is thought to' have escaped detection follo

g the first, event since apparently on1 an

1. intermitednt. failure existed. at,Jthat time and ince

'openfng tb trip breakers, allowed' the rods to fall-in and h i i reset; i

the' IED display data " "

codes for the m detector / encoder cards in the "A' gray"B" & Data Cabinets. l 7he w chnical t manual- for the DRPI system calls for !

Obcldg these gray codes to determine needed replacement d.d ' suspect carde. Following _ the second esent, the failure repeateds itself in troubleshooting and was i therefore subject '

to being detected.

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7. A. We di,tsct 'caua6 pf the tripwas personnel error as the field . current transducers were rly calibrated.

%e sc60t cause of the trip was te field current j trenc6acer calibration procedure was nat '

measuc1hy 'and test equipmentrequirements. .;9 ; used J

,B. As a result ot this trip.the following accians were taken: l

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1. RNea/ W :a xM Field Current Transducers, o

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2. Preform no load voltage checks of the rated to determine if design was 'actually seen int .e field.

'3. Confirmed tho. field . 3l l current reguh? tor OPERATED 1 SATISFACTORILY./ k 4 pA i

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ML20237L636

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