ML20005G736

From kanterella
Jump to navigation Jump to search
Monthly Operating Repts for Dec 1989 for Sequoyah Nuclear Plant
ML20005G736
Person / Time
Site: Sequoyah  Tennessee Valley Authority icon.png
Issue date: 12/31/1989
From:
TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML20005G735 List:
References
NUDOCS 9001230004
Download: ML20005G736 (16)
v • d • e


Text

F  :

e 'e TENNESSEE VALLEY AUTHORITY-NUCLEAR POWER GROUP SEQUOYAH NUCLEAR PLANT-MONTHLY OPERATING REPORT DECEMBER 1989 UNIT 1 DOCKET NUMBER 50-327-.

LICENSE NUMBER DPR-77 UNIT 2 DOCKET NUMBER 50-328 LICENSE NUMBER.DPR-79 l

l l

I l

J

'j,j$12gggg$ ,0N) f7 L a

( a OPERATIONAL

SUMMARY

DECEMBER 1989 UNIT 1 Unit 1 generated 700,500 MWh (gross) of electrical power during December with a capacity factor of 79.59 percent. A reduction in reactor power level was initiated on December 1, 1989, at 2100 (EST), for the performance of the ice condenser lower inlet door test and system walkdowns. Reactor power increase to 100 percent was delayed when problems occurred with HDT-3 Valves 6-106 A and B. Unit 1 reached 100 percent power level again on December 7, 1989.

On December 10, 1989, with Unit 1 in Mode 1 (100 percent power), a turbine trip / reactor trip occurred at 1047 (EST). The trip resulted from a high-high feedwater level of 75 percent in S/G 3. The trip was preceded by a secondary side transient, which resulted in a turbine runback to approximately 80 percent load.

Unit 1 was tied online on December 12, 1989, at 2257 (EST). The unit again reached 100 percent reactor power level on December 15,1989, at 0600 (EST).

On December 21, 1989, at 0842 (EST), the power level was decreased to approximately 80 percent for ten hours for CBP C maintenance and reached 100 percent reactor power at 1805 (EST), that same day.

Unit 1 operated at 100 percent power from December 21, 1989, at 1805 (EST),

until December 29, 1989, at 1706 (EST), when the power level was decreased to extend the life of the core with reduced load demands expected on the grid.

Unit I was operating at approximately 75 percent reactor power at the end of December.

9 r l n

I

UNIT 2 Unit 2 generated 818.580 MWh (gross) of electrical power during December with a capacity factor of 94 percent. The unit continued to operate at 100 percent power level untti December 15, 1989, when at 1049 (EST), the shift operations supervisor notified the Unit operator to decrease the load to 90 percent until the source.of the problem with HDT 3 level was determined. Reactor power reached 100 percent again on December 18, 1989, at.0335 (EST), but was again reduced because of erratic flow on Heater 3 drain system.

On December 20, 1989, with the reactor power level at 55 percent, the unit-operator began easing up the load to help meet load demands on the grid.

HDT 3 functioned normally, and 100 percent reactor power was reached on December 21, 1989, at 1634 (EST).

Unit 2 continued to ope' rate at 100 percent power level until December 29, 1989, at 2232 (EST), when the power level was decreased to extend the life of the core with reduced load demands expected on the grid. Unit 2 was operating at approximately 75 percent reactor power at the end of December.

POWER-OPERATED RELIEF VALVES (PORVs) AND SAFETY VALVES

SUMMARY

There were no challenges to PORVs or safety valves in the month of December.

OffSITE DOSE CALCULATION MANUAL (ODCM) CHANGES There were no changes to the ODCM in the month of December.

L i

fr FUEL PERFORMANCE Unit 1 The core average fuel exposure accumulated during December was 941.46 mwd /MTV, ,

with a total accumulated core average fuel exposure of 13,690.93 mwd /MTV.

Unit 2 i

The core average fuel exposure accumulated during December was 1,111.49 mwd /MTV, with a total accumulated core average fuel exposure of 8,244.63 mwd /MTV.

SPENT FUEL PIT STORAGE CAPABILITIES The total storage capability in the SFP is 1,386 bundles. However, there are six cell locations that are incapable of storing spent fuel. Four locations (A10, All, A24, and A25) are unavailable because of a suction-strainer conflict, and two locations (A16 and A21) are unavailable because of an instrumentation conflict. Presently, there is a total of 428 spent-fuel bundles stored in the SFP. The remaining storage capacity is 952 bundles.

3 4

b

I . .

. GLOSSARY OF VARIOUS ABBREVIATIONS Page 1 of 3

1. ABGTS - Auxiliary Building Gas Treatment System
2. ABSCE - Auxiliary Building Secondary Containment Enclosure
3. AB(1) - Auxiliary Building (Isolation)
4. AFW - Aux 111ary Feedwater 5.. AFWP1 - Aux 11 airy feedwater Pump Turbine
6. A01 - Abnormal Operating Instruction
7. ASOS - Assistant Shift Operations Supervisor ,
8. AVO - Assistant Unit Operator
9. BAE - Boric Acid Evaporator
10. BAT - Boric Acid Storage Tank
11. : BIT - Boron Injection Tank '
12. CAQR - Condition Adverse to Quality Report
13. CAR -Corrective Action Report
14. CBP - Condensate Booster Pump
15. CCP - Centrifugal Charging Pump
16. CCS - Component Cooling System
17. CCW .- Component Cooling Water ,
18. CDHE - Condensate Demineralizer Haste Evaporator l
19. CM - Corrective Maintenance
20. CRI - Control Room Isolation
21. CREVS - Control Room Emergency Ventilation System
22. CSS (CS) - Containment Spray System *
23. CVCS - Chemical Volume and Control System
24. CVI - Containment Ventilation Isolation
25. D/G(s) - Diesel Generator (s)
26. DCN - Design Change Notice  ;
27. DCR - Design Change Request
28. DI - Demineralizer
29. DR - Discrepancy Report
30. ECCS - Emergency Core Cooling System
31. ECN - Engineering Change Notice
32. EGIS - Emergency Gas' Treatment System
33. - Electrical Maintenance EM
34. EMI - Electromagnetic Interference
35. EQ - Environmentally Qualified / Environmental Qualification '
36. ERCH - Essential Raw Cooling Water
37. E/ES - Emergency Instruction ,
38. ESF - Engineered Safety Feature l
39. ESFA - Engineered Safety feature Actuation  !
40. FCR - Field Change Request-
41. FCV - Flow Control Valve 3
42. FDCT - Floor Drain Collector Tank
43. FDS - Flow Differential Switch  ;
44. FIC - Flow Indicating Controllers
45. FSAR - Final Safety Analysis Report
46. FS - Flow Switch
47. FHI - Feedwater Isolation
48. FY - Fiscal Year
49. GOI - General Operating Instruction
50. GPM

- Gallons Per Minute '

)

!= . .

. GLOSSARY OF VARIOUS ABBREVIATIONS Page 2 of 3  :

51. HDT(P) - Heater Drain Tank (Pump).
52. HD - Hold Order
53. IM - Instrument Hechanic/ Instrument Maintenance
54. IMI - Instrument Maintenance Instruction
55. LCV - Level Control Valve  !
56. LER - Licensing Event Report
57. LCO - Limiting Condition for Operation ,
58. - Loss-of-Coolant Accident

~

LOCA

59. LS - Level Switch
60. LTA - Lost-Time Accident
61. MLTE - Measuring and_ Test Equipment .
62. mA - Milliampere  :
63. MAST- - Maximum Allowable Stroke Time
64. MCR - Main Control Room
65. MDAFWP - Motor-Driven Auxiliary Feedwater Pump
66. MFI - Main feedwater Isolation *
67. MFW - Main Feedwater
68. MFWRV - Main feedwater Regulating Valves 1
69. MFP - Main Feedwater Pump
70. MI - Maintenance Instruction
71. MODS - Modifications
72. MOV - Motor Operated Valve
73. MR/ MREM - Man-rem
74. MSI - Main Steam Isolation
75. MSIV - Main Steam Isolation Valve
76. MSR - Molsture Separator Reheaters
77. MWe - Megawatts electric
78. MWt - Megawatts thermal  ;
79. NE - Nuclear Engineering (formerly Division of Nuclear Engineering)
80. NIS - Nuclear Instrumentation System
81. NMUDI - New Makeup Detonized System
82. NSS - Nuclear' Security Service
83. NSSS - Nuclear Steam Supply Systems 84 O&PS - Office and Power Stores Building
85. PDS - Pressure Differential Switch
86. PDIS - Pressure Differential Indicator Switch-
87. PM - Preventive Maintenance
88. PMT - Postmodification Test
89. PORC - Plant Operations Review Committee
90. PORV - Power-0perated Relief Valve
91. PRO - Potential Reportable Occurrence
92. PRT - Pressure-Relief Tank-
93. QMD5 - Qualification Maintenance Data Sheet
94. RCS/(P) - Reactor Coolant System /(Reactor Coolant Pum,1
95. RCPM - Re ttor Coolant Pump Motor
96. RETS - Re lological Effluent Technical Specification
97. RHR - Rt.idual Heat Removal
98. RM - Radiation Monitor (RAD Monitor / RAD MON)
99. RPI - Rod Position Indicator 100. RWST - Refueling Water Storage Tank l

l l

c .. 1

GLOSSARY OF'VARIOUS-ABBREVIATIONS

-Page 3 of 3 101'. SCRt - Significant Condition Report 102. S/D: .- Shutdown.

-103. SFP - Spent fuel P1t-104. S/G(s)- Steam Generator (s) 105. SI- - Surveillance. Instruction /or Safety Injection-106. SMI - Special Maintenance Instruction-107. SOS ~ - Shift-Operations Supervisor 108.. SOI - System Operating Instruction-

-109.. SQN - Sequoyah Nuclear Plant 110. SR, - Surveillance Requirement / Source Range' 111. SSPS - Solid-State Protection System 112. TACF. - Temporary Alteration Control Form' 113.= TDAFHP - Turbine-Driven Aux 11iary Feedwater Pump.

114. .TI .

- Technical: Instruction i 115. TS(s) - Technical Specif.1 cation (s)'

116. TSC- Technical Support Center 117. TVA - Tennessee Valley AuthorityL 118. UC1/G - Microcuries Per Gram 119. U1 - Unit 1 '

120. U2 - Unit 2 121. UHI - Upper Head Injection 122. UO/(S)RO - Unit Operator /(Senior) Reactor Operator-123. VLV - Va' - 1 124. WP - ian.

125. .HR - ' Request

[

t I

i l

l l

l l

p

, -CLOSSARY OF VARIOUS SYSTEMS OF:SEQUOYAH NUCLEAR PLANT v .

n.

SYSTEM ..

CODE' ' SYSTEM TITLE 1 Main Steam System (Turbine),(MSR) 2: . Condensate System (FH' Heaters)'

-3 Main and Auxiliary feedwater System 5 Extraction Steam System-6 Heater Drains and. Vents System 14 Condensats Demineralizer-15c Steam Generator Blowdown System 24 . Raw Cooling Water: System-27 Condenser Circulating Hater System

'30 Ventilating System.

35 Generator Cooling Systems:

36 Feedwater/ Secondary Treatment System

'37 Gland Seal-Water System

46. > Main / Auxiliary Feedwater' Control. System 47- Turbogenerator Control System 54 Injection Water System

'58 ' Generator Bus Cooling System 61 Ice Condenser System 16 2 Chemical and Volume Control System 1 63 :SafetysInjection. System .

64~ Ice Condenser Containment System 65 Emergency Gas Treatment. System.

67 Essential. Raw Cooling Water System 68 Reactor Coolant System (Steam Generator)  !

70 . Component Cooling. System  !

74 Residual Heat Removal System j 82 Standby Diesel' Generator Syste.m-87 Upper Head Injection System 90 Radiation Monitoring 1 System 250 AC/DC Low Voltage Power ~ .

268 Hydrogen Mitigation System l

i k

)

-i

9 e

.. RADHASTE

SUMMARY

~

f:-

  • 1 December,1989- i
1. Total. volume of solid waste shipped offsite:.
  • A. Dry active waste: 1422.2 ft activity: 1.5699 curies i

B. Spent resins, sludges, bottoms, oll: -214.9 ft

Activity: 1.0605 curies-l r Shipped: Barnwell, S.C.' - December ~ 4.'1989-(1)(3)

December- 6, 1989-(1)(3) '

December'13, 1989 (1)(3)

December 19, 1989 (1)'

December 21, 1989-(1)(2) i December 28, 1989 (1)(3)~

December. 29, 1989 (1)(3)

December- 29,1989 (1)(3) y December 30, 1989 (1)(3) 4 December 30, 1989 (1)(3) '
2. Radwaste m stte and awaiting shipment: r A.- Resin in storage: 260 ft' B. Estimated resin that will be generated: 100'ft '

C. Dry active waste awaiting shipment: 0 f t' 1 - Dry active waste 2 - Spent resin, sludges, bottoms, oil 3 - Haste shipped from Quadrex volume reduction facility 4 - Haste shipped from SEG volume reduction facility .,

l l

l

f.o, 4

. c. .

lo f 7 ,

UNIT 1 REACTOR HISTOGRAM ^ ANALYSIS ~

. f. ,

Unit 1 k

e' s

T

\

lr 4

I i

.j u

)

I i

I l

1 1

I 1 l

l a

i

' l.

h ll

,j

~

. UNIT 2 REACTOR HISTOGRAM ANALYSIS i

Unit 2

1. Unit operating at 75 percent power.

Began load' decrease for repair head-vent valves.- i

2. Reactor power at 45 percent.
3. Reactor power,atl38 percent, ,

4 Reactor power at 28 percent. ,

5. Reactor power.at 20' percent,'still decreasing-load. ,
6. Reactor. power at 0 percent.  ;
7. Began increase to 1Tpercent reactor" power.

i

8. Approximately 2 percent reactor power, entered _ Mode 1.

'9. Reactor power at 14 percent. ,

10. Began power increase to 30 percent,
11. Reactor power at 30 percent.
12. Reactor power at 45 percent.
13. Resumed power increase.

'L

14. Terminated power increase at 84 percent , reactor power, 964 MW.,
15. Maintaining 85 percent reactor power-to extend life of core.
16. Started power increase to 100 percent to meet load demands.
17. Reactor power at 100 percent. Continued'at 100 percent through end.of month.

\

M .

1

,2 6

.- q' $

s i

i

~d l

t j

l 1

1 l

ij i

l 4 a 1

i 4 .

1 1

\

I GLOSSARY .1 2- 1

.1

-1 I

I

' \

-l l

1

.I 1

i h.

I

\

l l

l

-l l

1 1

1 1

i k

+

f I

p 4 ,

-}

wa .,- .

S-p.

~

- UNIT.1--

DECEMBER.

CAPACITY' LOSS

.(Generation)L i PERCENT MW./1183

. River Temperature; - 0.20. ,

High. Throttle Pressure , - 0.34

}

Auxiliary Steam Loads- + 0.05:

P Leaking Valves . + O.04 t New HSR' Tubes - 0,07 Unaccounted + 0.44-Not at 100 Percent Power- t20.70i  !

+20,62 AVAILABILITY LOSS (Time Online)-

Unit 1 tripped on-12/10/89 at :8.09-1047 (EST), and returned to' '

service on 12/12/89 at'2257 (EST).

k I

1 l

4

~ '

p; ~

r 4 .. ,,

_j s' \

e. .i UNIT-2 -

DECEMBER <

a CAPACITY LOSS (Generation):

PERCENT MW./1183: i River Temperature- - 0.19 Turbine Inefficiencies .+ 0.46 While at Low Power Dirty Condenser Tubes + 0.06 High Throttle Pressure - 0.26 Improved MSR Performance - 0.03:

Leaking Valves + 0,19

'Not at 100 Percent -+ 5.78-Auxiliary' Steam Load + 0.19' Unaccounted' + 0.80

~

+ 7.00 AVAILABILITY LOSS l (Time Online)

None

')

l l

E t

1 l-i I

I k i

1

!' i l 1 t

Retrieved from "https://kanterella.com/w/index.php?title=ML20005G736&oldid=2514785"