ML19256A300

Monthly Oper Rept for Nov 1978

ML19256A300
Person / Time
Site:	Fort Saint Vrain
Issue date:	12/01/1978
From:	Gahm J PUBLIC SERVICE CO. OF COLORADO
To:
Shared Package
ML19256A301	List: ML19256A300 ML20062E877
References
NUDOCS 7812130167
Download: ML19256A300 (5)

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PUBLIC SERVICE COMPANY OF COLORADO FORT ST. VRAIN NUCLEAR GENERATING STATION FDNTHLY OPERATIONS REPORT No. 59 NOVEFBER, 1978 5

This report contains the highlights of the Fort St. Vrain, Unit No.1 acti-vities, operated under the provisions of the Nuclear Regulatory Commission Operating License, DPR-34. This report is for the month of November,1978.

1.0 NARRATIVE SUSD!ARY OF OPERATING EXPERIENCE AND MAJOR SAFETY RELATED FMINTENANCE Tests to investigate the primery system temperature fluctuations were performed on November 1,1978, through November 4,1978. A number of low amplitude fluctuations were experienced at reactor power levels be-tween 28% and 50% of rated and with core pressure dif ferentials of 2.9 psid. These fluctuations were initiated by: orifice valve motions , cir-culator speed changes , and power level changes. A turbine trip occurred on November 2,1978, on low main steam temperature during circulator speed r.hanges for these tests.

On November 6,1978, an inadvertent opening of a 480 volt breaker caused a temporary loss of power to some plant equipment and a reduction in plant load. The plant was returned to normal a short time later.

The reactor was operated at approximately 60% power, with an electrical output of 190 to 195 Mw until November 13, 1978. Main steam / reheat steam temperatures were 1,000/1,000 and primary coolant oxidants were less than 10 ppm and slowly decreasing.

On November 13, 1978, reactor power was raised to 62% at 8:15 am. At 1:45 pm "C" helium circulator tripped due to a drain malfunction. Load was reduced to less than 30% power in order to recover the circulator.

Shortly thereaf ter, No. 2 bearing on the main turbine generator started indicating excessive vibration. The turbine tripped from high vibration at 4:38 pm. That same evening, problems were encount ; red with off gassing of o:eidants from the helium purification system back into the primary coolant due to liquid nitrogen system malfunction. The main turbine generator was returned to service on November 15,1978, and by 11:00 pm on November 16, 1978, was back to 60% reactor power and 195 MN(e).

Primary coolant oxidants were again under 10 ppm and the plant operated until November 27, 1978, at these conditions.

On November 27, 1978, a fire occurred on Loop 1 bypass system trap drain line from leaking System 91 oil. The fire was immediately extinguished with no permanent damage incurred.

On November 28, 1978, a main condenser leak developed on the north side of the water box with resulting deterioration of condensate water quality.

Approximately 1,000 tubes were plugged in this side of the condenser as was done on the south side approximarely six months ago. The north side water box was put back in service on December 5,1978, with no apparent leaks.

On November 29,1978, "B" helium circulator tripped from loss of bearing water during a filter change over which caused a momentary low differen-tial pressure spike to the Plant Protective System sensors. "B" circula-l tor was restored to service in approximately ten minutes.

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1.0 NARRATIVE

SUMMARY

OF OPERATING EXPERIENCE AND MAJOR SAFETY RELATED MAINTENANCE (continued)

On November 29, 1978, service water ingress to the buffer system from a breach in a helium recovery compressor resulted in "B" and "C" circu-lator trips. The,, reactor was manually scrarxied when the turbine tripped from spurious nois;e to the fast closing IV circuit caused by arming of the runback circui' when "B" and "C" circulators tripped.

On November 30, 1978, repair of "A" and "B" helium recovery compressors and clean up of the secondary coolant continued in preparation for re-start of the reactor.

2.0 SINGLE RELEASES OF RADI0 ACTIVITY OF RADIATION EXPOSURE IN EXCESS OF 10% OF THE ALLOWABLE ANNUAL VALUE None

3. 0 INDICATIONS OF FAILED FUEL RESULTING FROM IRRADIATED FUEL EXAMINATIONS None 4.0 MONTHLY OPERATING DATA REPORT At tacited 2

s

cPERATINc cATA Rr?onT DoCnET No. 50-267 DATE 781201

. COMPLu.w EY J. W. Cahn TELEPHONE (303) 785-2253 CPEMTINO STATUS NOTES

1. Unit Name: Fort St. Vrain, Unit No. 1

2. Reporting Period: 781101 to 781130

3. Licensed Thermal Power (Wt): 842

4. Nameplate Rating (Gross W e): 342

5. Design Electrical Rating Oiet We): 330

6. Maximu= Dependable Capacity (Gross We): 342

7. Maximuti Dependabic Capacity (Net We): 330

8. If Changes Occur in Capacity Ratings (Items Nu=ber 3 Through 7) Since Last Report, Give Reasens:

None

9. Power Level To Which Restricted, If Any (Net We): 231

10. Reasons for Restrictions, If Any: NRC restriction (70%) pending resolution of certain Final Safety Analysis' Report and Technical Specification bases discrepancies.

This unit is in the power ascension phase of startup testing program.

This Month Year to Date Cumulative

11. Eours in Reporting Period 720 8,016

12. Number of Bours Reactor Was Critical 688.1 6.165.1 12,799.6

13. Reactor Reserve Shutdown Hours 0.0 0. 0 0. 0

14. Ecurs Generator on-Line 667.8 3,957.3 7, 95. 3

15. Unit Reserve Shutdown Bours 0. 0 0. 0 0.0

16. Gross Thermal Energy Generated (WH) 303,181 1,770,400 2,929,188

17. Gross Electrical Energy Generated (W H) 110,594 564,'10 849,687

18. Net Electrical Energy Generated (W d) 104.820 516.6'< 758,975

19. Unit Service Factor N/A N/A N/A

20. Unit Availability Factor N/A N/A N/A

21. Unit Capacity Factor (Using MDC Net) N/A N/A N/A

22. Unit Capacity Factor (Using DER Net) N/A N/A N/A

23. Unit Forced Outage Rate N/A N/A N/A

24. Shutdowns Scheduled over Next 6 Monchs (Type, Date, and Duration of Each):

Refueling March.1979; 2 months

[5. If' Shut Down at End of Report Period, Estimated Date of Startup: December 3, 1978

/2 A. Units In Te,st Status (Prior to Coc:mercial Operation): Forecast Achieved

.J INITIAL CRITICALIIT 740201 740131 Mh INITIAL ELECTRICITY 7612 761211 g J ND f T 8, f OD M . *T .*

tHIT SilUTDOWNS AND POWER REDUCTONS *

• DOCKET NO. 50-267 UNIT FWit Fort St. Vrain, Unit No1 DATE 781201 C0ftPLETED BY J. W. Cahm REPORT !!ONTil November, 1978 TELEPironE (303) 785-2253

!!Elll0D OF SIIUTTING DOWN SYSTEM COMPONENT NO. DATE TYPE DURATION REASON REACTOR LER f CODE CODE CAUSE AND CORRECTIVE ACTION TO PREVENT RECURRENCE 78-33 781102 F 0.4 11 4 N/A N/A N/A During performance of special testing, low main steam temperature caused an automatic trip of the turbine-generator .

Reactor was not shut down.

78-34 78111/< F 19.9 11 4 N/A .

N/A- N/A During power reduction, excessive differentini. temperatures between hot reheat and main steam temperatures caused a high bearing vibration trip of the turbine-generator. Reactor was not shut down.

78-35 78112! F 31.9 A 2. 5 N/A N/A N/A Buf fer helium upset caused automatic trip of two circulators and the turbine -

generator. Reactor was manually scrammed.

SUMMARY

Plan to continue Operation for electric production until release to continue fluctuation and/or power ascension testing above 70% is received from Nuclear Regulatory Commission.

AVERAGE DAILY UNIT POWER LEVEL Docket No. 50-267 Unit Fort S t. Vrain, Unit No. 1 Date 781201 Completed By J. W. Gahm Telephone (303) 785-2253 ,

Month November, 1978 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (FMe-Net) (1Me-Ne t) 48 17 190 1

50 18 194 2

88 19 195 3

96 20 194 4

90 21 192 5

108 22 190 6

146 23 190 7

8 166 24 ,.,,, 192 176 25 191 9

182 26 191 10 183 27 192 11 181 28 177 12 185 29 79 13-115 30 0 14 37 31 N/A 15 16 155

• Generator on line but no net generation,

REFUELING INFORE\ TION

1. Name of Facility. Fort St. Vrain, Unit No. 1

2. Scheduled date for next refueling March 1, 1979 clutdown.

3. Scheduled date for restart May 1, 1979 follouing refueline. ,

4. Will refueling or resumption of operation thereafter require a technical specification change or other licensa amendnent? Yes*

If answer is yes, what, in To facilitate insertion of eight fuel test general, will these be? elements If answer is no, has the reload

• NOTE: If Technical Specification change fuel design and core configura- approval is not received from NRC in time tion been reviewed by ycur Plant for refueling, then the answer to #4 is NO Safety Review Committee to deter- and the reload fuel and graphite design mine whether any unreviewed have been reviewed.

safety questions are associated with the core reload (Reference 10CFR Section 50.59)?

If no such review has taken nlace, when is it scheduled?

5. Scheduled date(s) for submitting proposed licensing action and supporting information. January 9, 1978

6. Important licensing considera- Eight test fuel elements to allow:

tions associated with refueling, e.g., new or different fuel de- 1) Different fuel particle design.

sign or supplier, unreviewed '

design or performance anal fuis 2) To qualify near isotropic graphite, methods, significant changes in fuel design, new operating pro-cedures.

7. The nu=ber of fuel assemblies a) 1482 HTGR elements.

(a) in the core and (b) in the spent fuel storace pool. b) 0 in fuel storage wells.

8. The present licensed spent fuel Capacity is limited by size only to about pool storage capacity and the one third of core (approximately 500 HTGR size of any increase in licensed elements). No change is planned.

storage capacity that has been requested or is planned, in number of fuel assemblies.

- REFUELI :G INFOP2'.ATION (CONTINUED) t The projec:ed date of the 1986 under the Three Party Agree =ent

9. (Con:ract AT (04-3)-633) between DOE ,

last refueling that can be Public Service Co=pany of Colorado (PSCo) ,

edischarged to the spent fuel and General Ato=ic Co=pany.*

pool assu=ing the present licensed cacacity.

fuel discharged during

• The 1986 da:e is based on the understanding that spent the ter= of the Three Party Agree =ent will be shipped to the Idaho Na:ional the Idaho Che=ical Processing Engineering Labora:ory for storage by DOE at Plant (ICPP). The storage . capacity has evidently been sized to acco=odate fuel which is expected to be discharged during the eight year period covered by the Three Party Agreement.

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