1CAN028706, Monthly Operating Rept for Jan 1987
| ML20205B495 | |
| Person / Time | |
|---|---|
| Site: | Arkansas Nuclear  |
| Issue date: | 01/31/1987 |
| From: | Enos J, Gobell J ARKANSAS POWER & LIGHT CO. |
| To: | Bassett H NRC OFFICE OF RESOURCE MANAGEMENT (ORM) |
| References | |
| 1CAN028706, 1CAN28706, NUDOCS 8703270618 | |
| Download: ML20205B495 (7) | |
Text
o
,1 OPERATING DATA REPORT
. DOCKET NO:
50-313 DATE:
January. 1987 COMPLETED BY:J. N. GoBell TELEPHONE:
(501) 964-3251-OPERATING STATUS 1.
Unit Name:
Arkansas Nuclear One - Unit 1
- 2.
Reporting Period: January 1-31, 1987 3.
Licensed Thermal Power (MWt):
2,568 4.
Nameplate Rating (Gross MWe):
902.74 5.
Design' Electrical Rating (Net-MWe):
850
' 6.
Maximum Dependable Capacity-(Gross MWe):
883 7.
Maximum Dependable Capacity (Net MWe):
836 8.
If Changes Occur in Capacity Ratings (Items Number 3 Thr ough 7) Since Last Report, Give Reasons:
9.
Power Level To Which Restricted.
If Any (Net MWe):
None 10.
Reasons For~ Restrictions.
If Any:
None MONTH-YR-TO-DATE CUMULATVE 11.
Hours in Reporting Period....
744.0 744.0 106,243.0 12.
Number of Hours Reactor was Critical.....................
518.8 518.8 71,718.6 13.
Reactor Reserve Shutdown Hours........................
0.0 0.0 5,044.0 14.
Hours Generator On-Line......
501.4 501.4 70,207.2 15.
Unit Reserve Shutdown Hours..
0.0 0.0 817.5 16.
Gross Thermal Energy Generated (MWH)........................
938,903.0 938,903.0 164,664,658.0 11 7.
Gross Electrical Energy Generated (MWH)..............
313,670.0 313,670.0 54,540,530.0 18.
Net Electrical Energy-Generated (MWH)..............
293,398.0 293,398.0 51,919,434.0 19.
Unit Service Factor..........
67.4 67.4 6G.1 20.
Unit Availability Factor.....
67.4 67.4 66.9 21.
Unit Capacity Factor (Using MDC Net)..............
'47.2 47.2 58.5 22.
Unit Capacity Factor (Using DER Net)..............
46.4 46.4 57.5 23.
Unit Forced Outage Rate......
32.6 -
32.6 14.4 24.
Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):
25.
If Shut Down At End of Report Period.
Estimated Date of Startup:
26.
Units in Test Status (Prior to Commercial Operation):
Forecast Achieved INITIAL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION I> 1'k 8703270618 870131 PDR ADOCK 05000313 R
PDR I I L
- y; AVERAGE DAILY UNIT POWER LEVEL DOCKET NO:
50-313 UNIT:
One DATE:
' January 1987-COMPLETED BY: J. N. GoBell TELEPHONE:
(501) 964-3251 MONTH January-1987 DAY AVERAGE DAILY POWER LEVEL (MWe-Net) 1.............
160 2.............
202 3.............
297 4.............
462 5.............
415 6.............
'491 7.............
513-8.............
807 i
9.............
749 10............
-12 i
11............
-5 12............
-5 13............ -
14............
-5 15............
-6 16............
-8 17............
-13 18............
-30 19............
26 20............
333 21............
677 22:............
485 23............
420 24............
389 25............
839 26............
841 27............
845 28............
845 29............
828 30............
845 31............
846 AVGS:
394 INSTRUCTION On this format, list the average daily unit power level in MWe-Net for each
-day in reporting month.
Compute to the nearest whole megawatt.
1
NRC MONTHLY OPERATING REPORT
-OPERATING
SUMMARY
JANUARY 1987 UNIT ONE
' Unit One began the month operating at low power to complete main feed pump work. At 0150 hours0.00174 days <br />0.0417 hours <br />2.480159e-4 weeks <br />5.7075e-5 months <br /> on the first, power escalation was started with a hold for integrated control system testing, condensate polisher problems, and low power physics testing.
The physics testing was completed at 0417 hours0.00483 days <br />0.116 hours <br />6.894841e-4 weeks <br />1.586685e-4 months <br /> on the third and power escalation was begun. On the third, power had to be held due to control system problems and then was increased to 82% where it was held until 0858 hours0.00993 days <br />0.238 hours <br />0.00142 weeks <br />3.26469e-4 months <br /> on'the fourth for main feed. pump work.
Power escalation was then continued until 1250 hours0.0145 days <br />0.347 hours <br />0.00207 weeks <br />4.75625e-4 months <br /> on the fourth when power _was held for valve testing.
Power was then reduced to 54% power and held there until 0230 hours0.00266 days <br />0.0639 hours <br />3.80291e-4 weeks <br />8.7515e-5 months <br /> on the sixth to make repairs to a main feedwater block valve.
Power was increased to 90% and held there from 1115 hours0.0129 days <br />0.31 hours <br />0.00184 weeks <br />4.242575e-4 months <br /> to 1215 hours0.0141 days <br />0.338 hours <br />0.00201 weeks <br />4.623075e-4 months <br /> on the' sixth due to core xenon restrictions.
Power was then reduced to 45% until 1045 hours0.0121 days <br />0.29 hours <br />0.00173 weeks <br />3.976225e-4 months <br /> on the seventh for main feedwater pump work.
The power escalation was then continued and the unit reached 100% full power at 1400 hours0.0162 days <br />0.389 hours <br />0.00231 weeks <br />5.327e-4 months <br /> on the eighth.
Steam generator tube leak indications were found, and a power reduction for testing was initiated at 1938 hours0.0224 days <br />0.538 hours <br />0.0032 weeks <br />7.37409e-4 months <br /> on the ninth.
The leak was confirmed, and the manual power reduction was continued until the unit was taken off line at 2210 hours0.0256 days <br />0.614 hours <br />0.00365 weeks <br />8.40905e-4 months <br /> on the ninth.
The unit remained off line until 1317
. hours on the nineteenth.
The unit was again taken off line at 1345 hours0.0156 days <br />0.374 hours <br />0.00222 weeks <br />5.117725e-4 months <br /> on the nineteenth due to hydrogen seal oil problems and placed back on line at 1454 hours0.0168 days <br />0.404 hours <br />0.0024 weeks <br />5.53247e-4 months <br />.
The unit was then taken off line at 1520 hours0.0176 days <br />0.422 hours <br />0.00251 weeks <br />5.7836e-4 months <br /> due to control problems, and finally placed back on line at 1542 hours0.0178 days <br />0.428 hours <br />0.00255 weeks <br />5.86731e-4 months <br /> on the nineteenth.
Power was escalated to 30% where it was held from 2100 hours0.0243 days <br />0.583 hours <br />0.00347 weeks <br />7.9905e-4 months <br /> on the nineteenth until 0700 hours0.0081 days <br />0.194 hours <br />0.00116 weeks <br />2.6635e-4 months <br /> on the twentieth due to feedwater chemistry problems.
The normal power escalation was then continued until indications of a feedwater heater tube leak caused a power reduction to be initiated at 1618 hours0.0187 days <br />0.449 hours <br />0.00268 weeks <br />6.15649e-4 months <br /> on the twenty-first.
The tube leak was confirmed, and the unit was taken off line at 2146 hours0.0248 days <br />0.596 hours <br />0.00355 weeks <br />8.16553e-4 months <br /> on the twenty-third to repair the leak.
The unit was placed back on line at 0746-hours on the twenty-fourth, and the unit reached 100% power at 1900 hours0.022 days <br />0.528 hours <br />0.00314 weeks <br />7.2295e-4 months <br />.
Power was reduced at 0404 hours0.00468 days <br />0.112 hours <br />6.679894e-4 weeks <br />1.53722e-4 months <br /> on the twenty-ninth for physics testing, and the unit was back at 100% power at 1920 hours0.0222 days <br />0.533 hours <br />0.00317 weeks <br />7.3056e-4 months <br /> where it remained through the end of the month.
UNIT SHUTDOWNS AND POWER REDUCTIONS REPORT FOR JANUARY 1987 DOCKET NO 50-313 UNIT NAME ANO Unit 1 DATE January, 1987 COMPLETED BY J. N. GcBell TELEPHONE 501-964-3251 Method of Licensee Cause & Corrective Duration Shutting Event System Component Action to l
No.
Date Type (Hours)
Reason 2 Down Reactor 3 Report #
Code 4 Code 5 Prevent Recurrence 8701 01/01/87 F 0
A 5
N/A N/A N/A Power escalation after i
startup delayed to correct leaks and control problems found during startup.
8702 01/09/87 F 231.1 A
1 N/A AB SG Steam generator tube leak.
8703 01/19/87 F 1.1 A
1 N/A TI TCV Hydrogen seal oil problems.
8704 01/19/87 F 0.4 A
1 N/A TG SC TG control problems.
8705 01/23/87 F 10.0 A
1 N/A SJ HX Feedwater heater tube leak.
1 2
3 4
F:
Forced Reason:
Method:
Exhibit G - Instructions 5:
Scheduled A-Equipment Failure (Explain) 1-Manual for Preparation of Data B-Maintenance or Test 2-Manual Scram.
Entry Sheets for Licensee C-Refueling 3-Automatic Scram.
Event Report (LER) File (NUREG-D-Regulatory Restriction 4-Continuation 1022)
E-Operator Training &
5-Load Reduction License Examination 9-Other s
F-Administrative Exhibit I - Same Source G-Operational Error (Explain)
H-Other (Explain)
DATE:
January, 1987 REFUELING INFORMATION 1.
Name of facility:
Arkansas Nuclear One - Unit 1 2.
Scheduled date for next refueling shutdown.
April 1988 3.
Scheduled date for restart following refueling. June 1988 4.
Will refueling or resumption of operation thereafter require a technical specification change or other license amendment?
If answer is yes, what, in general, will there be? If answer is no, has the reload fuel design and core configuration been reviewed by your Plant Safety Review Committee to determine whether any unreviewed safety questions are associated with the core reload (Ref. 10 CFR Section 50.59)?
Unknown at this time.
Cycle design has not been finalized.
5.
Scheduled date(s) for submitting proposed licensing action and supporting information.
If necessary, March 1988.
6.
Important licensing considerations associated with refueling, e.g., new or different fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel design, new operating procedures.
Zircaloy spacer arids, reconstitutable upper end fitting, aray axial power shaping rod assemblies, and "retainerless" assembly design.
7.
The number of fuel assemblies (a) in the core and (b) in the spent fuel storage pool, a) 177 b) 448 8.
The present licensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned, in number of fuel assembifes.
present 968 increase size by 0 9.
The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity.
DATE:
1997 (Loss of fu11 core offload capability)
4 ANNUAL REPORT OF SAFETY VALVE AND RELIEF VALVE FAILURES AND CHALLENGES This annual report.is submitted in the January Monthly Operating Report in response to requirements implemented as a result of NUREG-0737, Item II.K.3.3 and to fulfill Technical Specification reporting requirements (TS 6.12.2.4 for Unit 1 and TS 6.9.1.5.c for Unit 2).
For ANO-1, no challenges to the primary system code safeties nor electromatic relief valve (ERV) have occurred in the year 1986.
For ANO-2, no challenges to the primary system code safeties have occurred in the year 1986.
However, on September 24, 1986 an automatic reactor trip occurred.
Post trip evaluation of the transient data showed indications that a primary system code safety valve had partially lifted prematurely' l
during the event.
This event is further described in LER 86-012-00.
ANO-2
~does not have an ERV.'
a E ARKANSAS POWER & LIGHT COMPANY POST OFFICE BOX 551 UTTLE ROCK, ARKANSAS 72203 (501) 371-4000 February 17, 1987 1CAN028706 Mr. Harold S. Bassett, Director Division of Data Automation and Management Information Office of Resource Management U. S. Nuclear Regulatory Commission Washington, D. C.
20555 i
SUBJECT:
Arkansas Nuclear One - Unit 1 Docket No. 50-313 License No. DPR-51 Monthly Operating Report
Dear Mr. Bassett:
The Arkansas Nuclear One - Unit 1 Monthly Operating Report for January 1987 is attached.
Very truly yours,
. Ted Enos, Manager Nuclear Engineering and Licensing JTE:MCS:sg Attachment cc:
U. S. Nuclear Regulatory Commission Region IV 611 Ryan Plaza Drive, Suite 1000 Arlington, TX 76011 ATTN:
Mr. Robert D. Martin Regional Administrator U. S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 ATTN:
Mr. James M. Taylor, Director lf(
Office of Inspection and Enforcement ZE
- MEMBER MICOLE SOUTH UTILITIES SYSTEM j