ML20195C019

Monthly Operating Repts for May 1988 for Sequoyah Nuclear Plant,Units 1 & 2

ML20195C019
Person / Time
Site:	Sequoyah
Issue date:	05/31/1988
From:	Shawn Smith TENNESSEE VALLEY AUTHORITY
To:	NRC
References
NUDOCS 8806220085
Download: ML20195C019 (78)

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TENNESSEE VALLEY AUTHORITY OFFICE OF NUCLEAR POWER SEQUOYAH NUCLEAR PLAN 1 MONTHLY OPERATING REPORT TO THE NUCLEAR REGULATORY COMMIF3IOh MAY 1988 UNIT 1 DOCKET NUMBER 50-327 LICENSE NUMBER DPR-77 UNIT 2 DOCKET NUMBER 50-328 LICENSE NUMBER DPR-79 Submitted by: t- Ah S. J. Smith, Plant Manager 4

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, s. .m TABLE OF CONTENTS Page

1. Operational Summary Performance Summary 1 Significant Operational Events 1-5 t

Fuel Performance and Spent Fuel Storage Capabilities 6 PORVs and Safety Valves Summary 6 Special Reports 6 Licensee Events 7-12 Radwaste Summary 13 Offsite Dose Calculation Manual Changes 13 II. Operating Statistics A. NRC Reports Unit One Statistics 14-16 Unit Two Statistics 17-19 B. TVA Reports Nuclear Plant Operating Statistics 20 Unit Outage and Availability 21-22 Reactor Histogram 23-25 III. Maintenance Summary Electrical Maintenance 26-27 Instrument Maintenance 28-29 Mechanical Maintenance 30-32 Modifications 33-42 IV. Offsite Dose Calculation Changes 43 0288f

k e n OPERATIONAL

SUMMARY

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PERFORMANCE

SUMMARY

May 1988 The following summary describes the significant operational activities for the month of May, In support of this summary, a chronological log of significant events is included in this report.

Unit I remained in an administrative shutdown the entire month because of design control review, configuration control updating, and resolution of significant employee concerns. Outage-related maintenance and modifications are being performed. Preparations are underway for restart and power operations. Unit I has been off line 1013 days.

Unit 2 went critical at 1220E, May 13, 1988--one of the major milestones for operation. At 2107E, May 13, 1988, the unit began generating power once again for the TVA system after a two and one-half year outage. The unit held at several points for fuel conditioning, chemistry, maintenanc , and other parameters. On May 31, at 0200E, the unit reached 100 percent producing 1120 MWo. During the power ascension to 100 percent, the unit had two reactor trips--one due to equipment failure and one to personnel error. The unit had been off-line 996 days.

SIGNIFICANT OPERATIONAL EVENTS Unit 1 Date Time Event 05/01/88 0001E The reactor was in mode 5. The administrative shutdown due to design control review, configuration control updating, and resolution of significant employee concerns continues.

05/31/88 2400E The reactor was in modo 5. The administrative shutdown due to design control review, configuration control updating, and resolution of significant employee concerns continues.

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05/01/88 0001E Mode 5, activities continue for power operation.

RCS at 1220F, zero pressure.

05/04/88 1330E Began pressurizer heatup.

2005E Investigated pressurizer level fluctuation. Suspect

( nitrogen / ale pockets in the pressurizer.

2021E Began venting the pressurizor to stabilize level.

2111E Level stabilized.

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o SIGNIFICANT OPERATIONAL 3 VENTS Unit 2 (Continued)

Date Time Event 05/05/88 0600E Initiated RCS heatup.

0816E RCS at 1570 F, 300 psi.

05/07/88 0811E RCS at 1880F, 330 psi.

1422E Preparing for mode 4.

1500E Entered mode 4.

05/08/88 0818E RCS at 3180F, 350 psi.

05/11/88 072SE Entered mode 3, 1616E RCS at 5110F, 2020 psi.

05/12/88 0436E Began pulling S/D banks.

0456E All S/D banks withdrawn.

0626E Began diluting RCS.

2209E S/D banks verified withdrawn.

2211E Entered mode 2.

05/13/88 0057E Diluting to criticality.

0954E Began pulling control rods.

1220E Reactor is critical.

1230E Reactor at 1%.

1823E Entered mode 1.

1824E Rolling main turbine.

2107E On? tine.

221?E Reactor at 25%, holding for fuql conditioning 218 MWe, 35/14/88 0156E Reactor at 30%, 262 NWe, holding foe chemistry.

1330E Started load decrease for turbine overspeed test.

1402E Offline.

O SIGNIFIC/NT OPERATIONAL EVENTS .

Unit 2 (Continued)

Date,_ Time Event 05/14/88 1526E Test complete, online, began load increase.

1623E Reactor at 30%, 253 MWe, holding for chemistry.

05/15/88 2240E Reactor power increased to 3 1.

05/16/88 0030E Reactor at 34%, 320 MWe.

0920E Began load increase at 3% per hour.

1020E Steam leak on main steam reheater, terminated load increase.

1345E Resume power ascension.

1715E Stopped load increase. Condensate demineralizer pumps pulling high ampheres.

1719E Reactor at 45%, 440 MWe, 2200E Began load increase.

05/18/88 0030E Reactor at 51%.

0858E Reactor at 74%, 795 MWe. NRC holdpoint.

05/19/88 1412E Reactor tripped, steamflow/feedflow mismatch with low level No. 3 S/G.

1622E Entered mode 3.

05/20/88 0003E Reactor critical.

0205E Entered mode 1, 5%.

0302E Rolling main turbine.

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0405E Online.

l 0624E Re.ctor at 30%, 297 MWe, holding for chemistry.

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0711E Began power increase.

l 0935E Reactor at 48%.

l 05/22/88 1617E Reactor at 58%, 670 MWo.

2225E Terminated load ir. crease. Reactor at 72%, 830 MWe.

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,SIGNIFICANT OPERATIONAL EVENTS Unit 2 (Continued)

Date Time Event 05/23/88 00288 Reactor trip, low flow in loop No. 4.

0135E Entered mode 3.

1220E Began S/D banks withdrawal.

1257E S/D banks withdrawn.

05/24/88 0230E Control rods withdrawn.

02415 Entered mode 2 0325E Reactor critical.

0354E 1% reactor power.

0441E Entered mode 1. 1 0515E Rolling main turbine.

0605E Online.

0728E Reactor at 30%, 300 MWe, holding for chemistry.

1450E Began power increase.

1533E Reactor at 35%, 378 MWe, putting main steam reheaters inservice.

1815E Began load increase.

2353E Reactor at 48%.

05/25/88 1835E Began load increase to 90%.

05/29/88 0001E Reactor at 87%.

0140E Terminate increase to perform charinel range l calibrations, 90% reactor power.

l 0205E Calibrat*ons complete, resume load increase.

0505E Reactor at 95%, 2080 MWe. Awaiting pecmission to go to 100% power.

2304E Began load increase to 100%.

l SIGNIFICANT OPERATIONAL EVENTS Unit 2 (Continued)

Date Time Event 05/31/88 0200E Reactor at 100%, 1120 MVe.

0944E Loop 2, high steam flow alarm came in. Reduced turbine load.

1022E Ir. creased turbine load, steam flow alarm in again.

1400E Decreased load slowly to clear steam flow alarm.

1604E Reactor at 99%, 1132 MWe.

2400E Reactor at 99%, 1128 MWe.

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FUEL PERFORMANCE Unit 1 The core average fuel exposure accumulated during May was 0 MWD /MTU with the total accumulated core average fuel exposure of 0 MVD/MTU.

Unit 2 The core average fuel exposure accumulated during May was 366.26 MVD/MTU with the total accumulated core average fuel exposure of 8463.76 MWD /MTU.

SPENT FUEL PIT STORAGE CAPABILITIES The total storage capability in the SFP is 1,386. However, there are five cell locations which are incapable of storing spent fuel. Four locations (A10, All, A24, and A25) are unavailable due to a suction strainer conflict, and one location (A16) is unavailable due to an instrumentation conflict.

Presently, there is a total of 348 spent fuel bundles stored in the SFP.

Thus, the remaining storage capacity is 1,033.

PORVs AND SAFETY VALVES

SUMMARY

No PORVs or safety valves were challenged in May 1988.

SPECIAL REPORTS The following special reports were submitted to NRC in May 1988.

2-88-09 On April 35, 1988, with unit 2 in mode 5. fire barrier (shield building equipment hatch elevation 734) was nonfunctional for an interval greater than seven days. On April 8, 1988, unit 2 was returned to cold shutdown, and the biological shield blocks were removed to provide access in the reactor building for steam generators tube leak testing and repair activities. The activitie, could not be completed within seven days, and it was decided to leave the equipment hatch open until completion. A fire watch was established and maintained until the biological shield blocks were reinstalled. The fire barrier was declared functional on May 4, 14P8.

2-88-10 On April 28, 1988, with unit 2 in mode 5. fire detectors for fire zones 112 and 113 (auxiliary building elevation 690, column line A-8 to A-15 and U to Q) were inoperable greater than seven days.

Modification of the motor-driven AFW pumps and BAT area coolers duct system and supports (WP 0177-01) located in the above specified fire zones involved extensive welding and grinding. To prevent spurious fire alarms which could result from smoka produced by welding, the fire detectors were made inoperable. A continuous fire watch was established and maintained until the modification was completed. Detectors were declared operable on May 13, 1988.

LICENSEE EVENT REPORT (3)

The following Ilcensee event reports (LERs) w9re cransmitted to the Nuclear Regulatory Commission in May 1988.

Description of Event LER 1-88018 On April 11, 1988, at approximately 0150E, a first out reactor trip annenclator was received in the MCR for steam flow / feed flow mismatch, coine.ident with low S/G 1evel. The alarm was acknowledged and than a similar first out reactor trip annunciatoc alarmed at approximately 0153E. A reactor trip did not occur :ts a result of these signals because the reactor trip breakers had previously been opened.

The immediate cause of this event has been attributed to Modifications personnel making radio transmissions from the No. 4 accumulator room to support valve testing. The room contains reactor protection system circuit.s from the No. 3 S/G 1evel and steam flow transmitters. The root cause of this event has been attributed to inadequate posting of signs to prohibit the use of portable radios in or near the accumulator rooms. As immediate corrective action, personnel will be better informed regarding the prohibition of radio transmission around the accumulator rooms by posting additional signs in the vicinity.

To prevent recurrence of this event, TVA will ensure that plant personnel are cognizant of the requirements of SQ036, "Control and Use of Portable Radios." Radios that are now being used b,7 plant personnel (other than those personnel in departments required to permanently maintain radios) will be required to be returned to a single location. Personnel that have a need to use a radio in the power block will be required to sign a form

! stating they are familiar with SQO36 program before a radio will be issued. In addition, TVA will review available documentation to detertaine if TVA procedure adequately addresdes new electronic equipment that has been installed during the extended outage and will investigate the feasibility of reducing the maxiinam power level of portable radios currently in use.

1-88019 On Apell 24, 1988, at 2204E, (the reactor trip breakers were open) a reactor trip signal was generated from a source range (SR) nuclear lostrument channel spike. The R0 acknowledged the alarm and subsequently contacted Modifications personnel that were known to be in containment welding. The RO had suspected a welding machine being used as the cause of the SR spike. It was operated at high frequency again to ascertain that it was the cause of the SR spike. Upon doing so, a similar spike and reactor trip signal were generated. On May 2, 109R. at 2108E, another reactor trip signal was generated from the 5.1 channel.

The R0 acknowledged the alarm ano then contacted Modifications personnel in the containment and in the auxiliary building that were known to be welding to locate welding machines that could

Description of Ev:nt LER 1-88019 have caused the spike. Troubleshooting ensued on two welding (cont.) machines in containment and one in the auxiliary building. On May 4, 1988, a welding machine in containment was identified as the source. It was removed from containment to be tested for proper radio frequency power transmissions. It had normal transmissions. The root cause of this event is attributed to the noise susceptibility of the existing SR chat.nel design.

Plant operations and maintenance experience with respect to SR channel noise susceptibility has been previously identified and will require hardware changes to correct. These changes will be made when the present Westinghouse nuclear instrumentation system is upgraded to meet Regulatory Guide 1.97 requirements.

As interim corrective actions, welders have been informed by memorandum that high frequency use of the welding machine is prohibited. A caution label has also been attached on the applicable welding machine to prohibit high frequency operation.

1-88S03 On April 29, 1988, at approximately 0510E, an NSS officer was discovered in a less than fully alert state. The officer was posted at the location as a compensatory measure for an inoperable alarm system around the protected area. He was working 12-hour shifts (1800 to 0600). At approximately 0510E, the officer failed to respond to a radio page. The NSS line supervisor checked on the officer to determine why he did not respond. The supervisor found the officer in a less than fully alert state. This event was caused by the officer allowing

, himself to get in a condition which made it easy to be less than fully alert. He was sitting in a security vehicle with his head down. As to corrective action, the officer was immediately relieved and a new officer was placed at the location. NSS will also go back to 8-hour shifts.

2-88020 This LER is being reported as a voluntary report to inform NRC of a problem which has generic ramifications to the rest of the industry concerning check valves being used as cor.tainment isolation valves in raw water systems. On April 22, 1988, at approximately 0700E, ERCW containment isolation valves 2-67-562A and 2-67-562C Mid not pass SI-158.1, "Containment Isolation Valve Leak Ra ' Test." These are check valves on the inboard side of the ELCd piping to the lower compartment cooler groups.

The leakage meas'tred from each of the valves were 507.9 standard cubic feet Isr hour. The allowable leakage for all the testable penetrations in accordance with TS 3.6.1.2 is 135.1. The valves were cleaned and retested with acceptable results. This event was caused by sediment collecting on the seating surface. This .

prevented the valves from backseating and forming a tight seal, An additional cause is that swing check valves are not effective ,

in raw water tystems when low leakage rates are required. This type of check vr.1ve has an industry history of no. passing leakage rate tests. In order to prevent recurrence of this

Drscription of Evtnt LER 2-88020 event, two actions will be initiated: (1) The short-term action (Cont.) involves ensuring the valves to the lower compartment coolers remain full open in order to maintain sufficient flow through the check valves to help prevent buildup of foreign material on the seating surface, and (2) long-term action will be the replacement of the ERCW containment isolation check valves with motor-operaced butterfly valves.

2-88021 On May 4, 1988, at approximately 14002, with unit 2 in mode 5, it was discovered during a quality assurance review of the January 9, 1988, performance of SI-258.2, "Testing of Molded Case and Lcwer Voltage Containment Penetration Circuit Breakers," that three additional unit 2 circuit breakers had to be tested to satisfy TS Sd 4.8.3.1.a.2. This SR requires functional testing to be performed on a representative sample of at least 10 percent of each type of lower voltage containment penetration circuit breakers on a rotating basis in order to maintain contaircuent penetration conductor over-current protective devices operable. This SR is implemented via the performance of SI-258.2 for unit 2. A similar procedure, SI-258.1, is used to implement the unit 1 containment penetration conductor overcurrent protective devices SR. Both sis include a list of breakers that are subject to testing for meeting the SR. Some of the breakers in these listings are marked with an asterisk. The asterisk refers to a footnote stating "breakers common to both unit I and unit 2." To support implementation of SR 4.8.3.1.a.2, a computer database has been developed from the listings in SI-258.1 and SI-258.2. As part of the technical input for developing the program, all breakers marked by an asterisk are common to both units. The scheduling program was then developed to select breakers from this database for functional testing based on the manufacturer, the required percentage of breaker type, and the d9te of previous breaker testing. In this case, however, breakers providing protection from unit 1 containment load faults, which were identified as common to both units !n SI-258.1, were also subject to selection when performing SI-258.2 and vice versa.

The root cause of this event is attributed to misinterpretation of LCO 3.8.3.1. As corrective action to meet SR 4.8.3.1, two Westinghouse Electric Corporation type EB circuit breakers and one General Electric Corporation type TW that provide unit 2 containment penetration overcurrent protection were tested on May 4, 1988, with satisfactory results. To prevent recurrence of this event, the footnote in SI-258.1 and in SI-258.2 will be deleted, and the database will be changed to remove the breakers listed in SI-258.1 ft om the unit 2 database. These corrective actions will be completed by July 15, 1988.

1-87039 This report provides additional information to the corrective Rev. 4 action TVA has tsken to prevent recurrence of the event and changes to the data in which long-term corrective actions will be accomplished.

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D7scriptien of Ev'nt

__LER 1-87042 This revision provides additional information relating to the Rev. 2 action TVA has taken to correct a condition where inadvertently !

startinr, fire pumps during a LOCA could have degraded the '

auxiliary power system and overloaded the emergency D/Gs. '

1-87049 This report provides details concerning an inadequate procedure Rey, I during construction resulting in improperly sized mator thermal overload protection.

1-87070 This revision provides additional information relating to a Rev. 4 delay in the preparation of D/G postmaintenance testing procedures.

1-88014 Rev. I This revision clarifies the root causes and includes an additional corrective action to be implemented to prevent recurrence.

1-88016 This revision provides additional informatien regarding an Rev. 1 investigation into the cause of the event and the corrective action to be taken by TVA to prevent recurrence.

2-88014 This revision updates the cause and corrective action sections.

Rev.1 This report provides details concerning an SR used to verify boron concentration in the cold leg accumulators which was not performed within the applicable timeframe.

ABBREVIATIONS Page 1 of 2

1. ABGTS -

Auxiliary Building Gas Treatment System

2. ABSCE -

Auxiliary Building Secondary Containment Enclosure

3. ABI -

Auxiliary Building Isolation

4. AFW -

Auxiliary Feedwater

5. AOI -

Abnormal Operating Instruction

6. AUO -

Assistant Unit Operator

7. BAT -

Boric Acid Storage Tank

8. BIT -

Boron Injection Tank

9. CAQR -

Condition Adverse To Quality Report

10. CCP -

Centrifugal Charging Pump

11. CCW -

Criponent Cooling Water

12. CRI -

Control Room isolation

13. CREVS - Control Room Emergency Ventilation System

14. CSS (CS) - Containment Spray System

15. CVI -

Containment Ventilation Isolation

16. D/G(s) - Diesel Generator (s)

17. DCR -

Design Change Request

18. DNE -

Division of Nuclear Engineering

19. ECCS -

Emergency Core Cooling System

20. ECN - Engineering Change Notice

21. EGTS -

Emergency Gas Treatment System

22. EMI - Electromagnetic Interference 23 EQ -

Environmentally Qualified / Environmental Qualification

24. ERCW -

Essential Raw Cooling Water

25. ESF(A) -

Engineered Safety Feature (Actuation)

26. FCV -

Flow Control Valve

27. FSAR -

Final Safety Analysis Report

28. FWI - Feedwater Isolation

29. GOI -

General Operating Instruction

30. GPM -

Gallons Per Minute

31. HO -

Hold Order

32. IMI -

Instrument Maintenance Instruction

33. LCV -

Level Control Valve

34. LCO -

Limiting Condition for Operation

35. LOCA - Loss Of Coolant Accident

36. MAST -

Maximum Allowable Stroke Time

37. MFI -

Main Feedwater Isolation

38. MFP -

Main Feedwater Pump

39. MOV - Motor Operated Valve 40 MSI - Main Steam Isolation

41. MSIV -

Main Steam Isolation Valve

42. MCR - Main Control Room

43. NSS -

Nuclear Security Service -

44. NSSS -

Nuclear Steam Supply System

45. PORC -

Plant Operatlon Review Committee

46. PRO - Potential Reportable Occurrence

47. RCS -

Reactor Coolant System

48. RHR -

Residual Heat Removal

49. RM -

Radiation Monitor (RAD Monitor / RAD MON)

50. RWST -

Refueling Water Storage Tank V

ABBREVIATIONS Page 2 of 2

51. SCR -

Significant Condition Report

52. SFP - Spent Fuel Pit

53. S/G(s) -

Steam Generator (s)

54. SI -

Surveillance Instruction /or Safety Injection

55. SMI -

Special Maintenance Instruction

56. SOI -

System Operating Instruction

57. SQN - Sequoyah Nuclear Plant

58. SR -

Surveillance Requirement

59. SSPS -

Solid State Protection System

60. TACF -

Temporary Alteration Control Form

61. TI -

Technical Instruction

62. TS(s) -

Technical Specification (s)

63. UO/R0 -

Unit Operator / Reactor Operator

64. WP -

Workplan

65. WR -

Work Request l

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i RADWASTE

SUMMARY

May 1988

1. Total volume of solid waste shipped offsite:

A. Dry active waste: 1032 ft.*. Activity: 2.114E' curies B.

Spentresins, sludges, bottoms: 188 ft.".

Activity: 4.2757E curies Shipped: May 19, 1988 Barnwell, Inc.

2. Radwaste onsite and awaiting shipment:

A. Resin in storage: 584.5ft."

B. Estimate resin that will be generated: 570 ft.'

C. Dry active waste awaiting shipment: 934.5 ft*

OFFSITE DOSE CALCULATION MANUAL CHANGES A change May (revision 19) to the Offsite Dose Calculation Manual was approved 3, 1988.

A copy of that revision is found in section IV of this report.

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0 g # 6 OPERATING STATISTICS (NRC REPORTS) i I

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OPERATING DATA REPORT DOCKET NO.00-327 DATE JUNE 09,1988 COMPLETED BY D.C.DUPREE TELEPHONE (615)870-6722 OPERATING STATUS

1. UNIT NAME: SEGUOYAH NUCLEAR PLANT, UNIT 1 NOTES:

2. REPORT PERIOD: MAY 1988

3. LICENSED THE:RMAL POWER (MWT): 3411.0

4. NAMEPLATE R/' TING (GROSS MWE): 1220.6

5. DESIGN ELEC1RICAL RATING (NET MWE): 1148.0

6. MAXIMUM DEPE NDADLE CAPACITY (GROSS MWE): 1183.0

7. MAXIMUM DEPENDABLE CAPACITY (NET MWE): 1148.0

8. IF CHANGES OCCUR IN sAPACITY RATINGS (ITEMS NUMDERS 3 THROUGH 7)SINCE LAST REPORT, GIVE REASONS:

9. POWER LEVEL TO WHICH RESTRICTED IF ANY(NET MWE):

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10. REASONS FOR RESTRICTIONS IF ANY:

THIS MONTH YR.-TO-DATE CUMULATIVE

11. HOURS IN REPORTING PERIOD 744.00 3647.00 60648.00

12. NUMDER OF HOURS REACTOR WAS CRITICAL 0.00 0.00 24444.91 13., REACTOR RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

14. HOURS GENERATOR ON-LINE 0.00 0.00 23781.13

15. UNIT RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

16. GROSS THERMAL ENERGY GENERATED (MWH) 0.00 0.00 77060971.91

17. GROSS ELECTRICAL ENERGY GEN. (MWH) 0.00 0.00 25976386.00

18. NET ELECTRICAL ENERGY GENERATED (MWH) -3328.00 -26468.00 24827855.00

19. UNIT SERVICE FACTOR O.00 0.00 39.21

20. UNIT AVAILADILITY FACTOR 0.00 0.00 39.21

21. UNIT CAPACITY FACTOR (USING MDC NET) 0.00 0.00 35.66

22. UNIT CAPACITY FACTOR (USING DER NET) 0.00 0.00 35.66

23. UNIT FORCED OUTAGE RATE 100.00 100.00 54.00

24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH):

25. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP:

STARTUP IS UNDETERMINED AT THIS TIME PENDING DESIGN CONTROL REVIEW, CONFIGURATION CONTROL UPDATING, AND RESOLUTION OF SIGNIFICANT EMPLOYEE CONCERNS.

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NOTE THAT THE THE YR. -TO-DATE AND CUnULATIVE VALUES HAVE DEEN UPDATED.

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SEQUOYAH NUCIEAR PIANT AVERAGE DAILY POWER IEVEL DOCKET No. : 50-327 UNIT : ONE L%TE : JUNE 02,1988 OCHPIErED BY : D.C.DUPREE TEI.EPf0NE : (615)870-6722 MJNIH: MAY 1988 AVERAGE DAILY POWER IEVEL AVEPAGE DAILY IO7ER IEVEL DAY (MWe Ne'.)

. DAY (MWe Net) 01 0 17 0 02 0 18 0 03 0 19 0 04 0 20 0 05 0 21 0 06 0 22 0 07 0 23 0 08 0 24 0 09 0 25 0 10 0 26 0 11 0 27 0

'2 0 28 0 l

13 0 29 0 14 0 30 0 15 0 31 0 16 0 I

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. q UNIT SIIUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-327 UNIT NAtfE Sequoyah One ,

DATE June 1, 1988 C0t1PLETED BY D. c. Dupree REPORT !!0NTil May 1988 TELEPHONE T6.3) s/U-6/zz w

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_ gg g oyg Lacensee g og Cause & Co ative l No. *) ate g 3g o ggg Event gg gg Act. to y 3o y gge Report # go gu Prevent R :urrence av e mep u ca  ;. va n

1 880101 F 744 F 4 Design Control, Configuration, Updating and Employ 2e Concerns.

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j 2 Reason: 3 tlethod:

I F: Forced 4 Exhibit G-Instructions S. Scheduled A-Eeguipment Failure (Explain) 1-itanual for Preparation of Data, B-!!aintenance or Test 2-!!anual Scram. Entry Sheets for Licensee C-Refueling 3-Automatic Scram. Event Report (LER) File D-Regulatory Restriction 4-Cont. of Existing (NUREG-0161)

E-Operator Training T. Licen:;c Examination Outage F-Ailministrative 5-Reduction S

! G-operational Error (Explain) 9-Other Exhibit I-Same Source 1

II-Other (Explain)

OPERATING DATA REPORT DOCKET NO. 50-328 DATE JUNE 08,1988 COMPLETED BY D.C.DUPREE TELEPHONE (615)B70-6722 OPERATING STATUS

1. UNIT NAME: SEGUOYAH NUCLEAR PLANT, UNIT 2 NOTES:

2. REPORT PERIOD: MAY 1988

3. LICENSED THERMAL POWER (MWT): 3411.0

4. NAMEPLATE RATING (GROSS MWE): 1220.6

5. DESIGN ELECTRICAL RATING (NET MWE): 1148.0

6. MAXIMUM DEPENDABLE CAPACITY (GROSS MWE): 1183.0

7. MAXIMUM DEPENDABLE CAPACITY (NET MWE): 1148.0 Q. IF CHANGES OCCUR IN CAPACITY RATINGS (ITEMS NUMBERS 3 THROUGH 7)SINCE LAST REPORT, GIVE REASONS:

9. POWER LEVEL TO WHICH RESTRICTED, IF ANY(NET MWE):

10. REASONS FOR RESTRICTIONS, IF ANY:

THIS MONTH YR.-TO-DATE CUMULATIVE

11. HOURS IN REPORTING PERIOD 744.00 3647.00 52608.00

12. NUMBER OF HOURS REACTOR WAS CRITICAL 380.92 380.92 22365.46 13., REACTOR RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

14. HOURS GENERATOR ON-LINE 365.98 365.98 21860.20

13. UNIT RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

16. GROSS THERMAL ENERGY GENERATED (MWH) 780704.22 780704.22 69908681.44

17. GROSS ELECTRICAL ENERGY GEN. (MWH) 249540.00 249540.00 23786320.00

18. NET ELEC".RICAL ENERGY GENERATED (MWH) 227907.00 176156.00 22684301.60

19. UNIT SERVICE FACTOR 49.19 10.04 41.55

20. UNIT AVAILABILITY FACTOR 49.19 10.04 41.55

21. UNIT CAPACITY FACTOR (USING MDC NET) 26.68 4.21 37.56

22. UNIT CAPACITY FACTOR (USING DER NET) 26.68 4.21 37.56

23. UNIT FORCED OUTAGE RATE 50.72 89.96 54.18

24. SHUTDOWNS SCHEDULED DVER NEXT 6 MONTHS (TYPE, DATE,~AND DURATION OF EACH):

25. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP:

l l NOTE THAT THE THE YR.-TO-DATE AND CUMULATIVE VALUES HAVE BEEN UPDATED, l

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SEQUOYAH NUCEAR PIANT AVERAGE DAILY ICWER IEVEL DOCITF NO. : 50-328 1

UNIT : 'IWO DATE : JUNE 02,1988 OCHPLEIED BY : D.C.DUPREE TELEEHONE : (615)870-6722 I

IONIH: MAY 1988 AVERAGE DAILY 10WER LEVEL AVERAGE DAILY ICWER IEVEL DAY (Mie Net) DAY (M4e Net) 01 0 17 420 02 0 18 726 03 0 19 457 04 0 20 0 05 0 21 254 06 0 22 590 07 0 23 16 08 0 24 253 09 0 25 745 j 10 0 26 780

\

11 0 27 792 ,

12 0 28 815 13 11 29 1039 14 225 30 1051 15 234 31 1095 16 339

j UNIT SlIUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-328 UNIT NAME sconovah Two DATE June 1. 1988 COMPLETED BY D. c. Dupree REPORT MONTl! MAY 1988 TELEPIIONE (615) 870-6722 w U E

_ gg N g oag Licensee g 3, gg Cause & Corrective l Wa. Date g 3y o, yjm Event gg gg Action to y gg a fgE Report # gu gu Prevent Recurrence 5~ EN5

> R .

3 880439 F 309.12 B* 9 Maintenance on pressurizer.

4 880514 S 1.40 B 5 Turbine overspeed test.

O T 5 880519 F 37.88 A 3 Steam flow /feedflow mismatch. Lo-Lo S/C No. 1 6 880523 F 29.62 F 3 Low flow caused by Maintenance recalibrating level indicators on loop 4 (RCS).

• Corrected.

2F: Forced 2 Reason: 3Hethod: 4 Exhibit C-Instructions S: Scheduled A-Equipment Failure (Explain) 1-!!anual for Preparation of Data B-!!aintenance or Test 2-!!anual Scram. Entry Sheets for Licensee C-Refueling 3-Automatic Scram. Event Report (LER) File D-Regulatory Restriction 4-Cont. of Existing (NUREG-0161)

E-Operator Training & License Examination Outage F-A.!ministrative 5-Reduction G-Operational Error (Explain) 9-Other 5 Exhibit I-Same Source Il-Other (Explain)

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9 4 S OPERATING STATISTICS l

(TVA REPORTS) h l

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NUCLEAR PLANT OPERATING STATISTICS SEQUOYAH NUCLEAR Plant Period Hours 744 Month _ _ MAY 19 88 Item No. Unit No. UNIT ONE l UNIT TWO PLANT 1 Averace Hourly Gross Load. kW 0 681,834 681,834 2 Maximum Hour Net Generation. MWh 0 1,108 _ _ _ _ _ 1,108 3 _ Core Thermal Energy Gen, GWO (t)2 0 32.5293 32.5293 4 Steam Gen. Thermal Energy Gen., GWD (t)2 0 32.6438 32.6438 8 5 Gross Electrical Gen., MWh 0 249,540 249,540 5 6 Station Use, MWh 3.328 21,633 24,961 h 7 Net Electncal Gen.. MWh -3.328 227,907 224,579

$ 8 Station Use, Percent N/A 8.67 10.0 9 Accum. Core Avg. Exposure, MWO/ Ton 3 0 8,464 8,464 10 CTEG This Month.106 8TU 0 2,664,544 2,664,544 11 SGTEG This Month,106BTU 0 2,673,917 2,673,917 I?

13 Hours Reactor Was Critical 0.0 380.92 380.92 14 Unit Use, Hours Min. 0:00 365:59 365:59 15 Capacity Factor, Percent 0.0 28.35 14.18 3 16 Turbine Avail. Factor, Percent 0.0 58.26 29.13 17 Generator Avail. Factor. Percent 58.39 0.0 29.20 C 18 Turbonen. Avail. Factor, Percent 0.0 58.66 29.33~

h 19 Reactor Avail. Factor. Percent 58.39 0.0 _ 29.20 2 20 Unit Avail Factor. Percent 0.0 49.19 -

24.60 21 Turbine Startons 0 4 4 22 Reactor Cold Startuns 0 1 1 93 g 24 Gross Heat Rate Htu/kWh N/A 10,680 10,680

{ 25 Net Heat RJte, Otu/kWh N/A 11.690 11,870 2 26 Gross Heat Rate Btu /kWh (w/o oil 10,680 C 97 Net Heat Rate Btu /kWh (w/o oil) 11,870 g 28 Throttle Pressure, psig N/A 878.34 878.3 g 29 Throttle Temperature, ' F N/A 530.90 530.9 j 30 Ext ust Piessure, inh 1 Abs. N/A 2.2 2.2 g 31 Intake Water Temo., 'F N/A 69.2 69.2

& 32 33 Main Feedwater, M lb/hr N/A 8.3 8.3

$ 34

[ 35 l 36 37 roit power capacity, ErPo 404.86 363.65 768.51 38 Accum. Cycle f ull Power Days, Ef PD 0.0 220.3781 220.38 g 39 oil rited for Generation. Galions l

1,584 2 40 oit Heatinn vaiuc. utu/ Gal. 138,000 41 Diesel Generation. MWh 24.

as

, Man. Hour Net Gen. Max. Day Net Gen Load MWh Time Date MWh Date f actor, %

a 43 1,108 0300E 5/31/88 26,288 5/31/88 26.83 O R emar k s ; if or HF NP this value is MWO/ST U and for SONP and WHNP this value is M$VD/MT U.

l 2(t) ir,,1 cates T hermal Energy.

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I v A 6%0C (PP 3-71)

UNIT OUTAGE AND AVAILABIL8(Y SEQUOYAH .

Nuclear Plant Ucensed Reactor Power 3411 MW(th) Unit No. . ONE a Generator Rateng 1220.6 gw(,) , .

Month / Yea, MAY 1988 Devgn Gross Electrical Rat ng 1183 MW Period Hours.. 744 T.m. un.t A .t.u. T.m. Nota. iwe METHOD OF UNIT T.=e inne b"U IN S ^ US CORRECTIVC ACTION Totas cen. NoeUwe Tiptune cen. saeat ter unet Out OUTAGE CAUSE TAKEN TO PREVENT On m, u ms ' u.a la DOWit DURING ms 8 J_. . . . u.= mslu m,'u m, ' u.= ms!u m.?u REACTOR REPCTITION l 00 TAGC 00 *00 00 '00

. l 24 *00 24 '00 24 .00 24s 00 i 2 00 '00 00 M e Destgn Control. Configuratton N/A- Mode 5 i 24 00 24 :00 24 800 24! 00 s a Updati v. and Employee 3 00 I00 00 '00

• 24 *00 24 i00 24 800 4 00 00 00 ;00 24 r OE , . concerns.

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. 24 -00 24 '00 24 !00 24 ' 00 e

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8 7 00 '00 00 s00 ' .

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e 12 00 a 00 00 !00 1 24 00 24 i 00 14 3 248 01 t i 13 00 100 00 i00 '

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• 14 00 ; 00 00 '00 24I00 24 00 ' '

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$ I7 00800 00 ;00 8 26 ,00 24 800 24 ;00 24 ! 00 '

e 18 00I00 00 t 00 e 24*00 24 l 00 24 800 24; 00 e e

19 00l00 00 000 r 24iOO 24 800 24 iOO 24a 00 ' '

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25 00;00 00 ;00 24a 00 24 l 00 1 24 '00 24e 00 '

26 00s00 00 s00 8 24l00 24 00 24 '00 240 00 i

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30 00 ; 00 00 iOO  ; 24l00 24 .00 24 iOO 24s 00 i .

31 00e00 00 800 e 24 i 00 24 400 24 !OO 243 00 e e Total 00 ! 00 00 l00  ? 744e00 744!00 744 iOO 744l 00 _>< XXX -

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REACTOR HISTOGRAM ~

SEQUOYAH UNIT ONE 100 90 -

g 80 -

Z d 70 -

1 E 60 -

b -

Y

$ 50 -

3 0 40 -

@ 30 -

I--

y 20 - .

10 -

Unit in Mode No. 5 0

1 I I 1 i i i i i i I i i i 1 0 4 8 12 16 20 24 28 32 MAY 1988 .

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REACTOR HISTOGRAM SEQUOYAH UNIT TWO 100 ,n -

10 f 90 - ,

g 80 - I z 6 m 7 O 70 - ,f, .'

x E 60 -

$ 50 -

ao s,

0-40 -

., 4 8d

@ 30 - 2 2 2s y 20 - .

10 -

0 1 I I I i i i I i l I I I I I I O 4 8 12 16 20 24 28 32 MAY 1988

' REACTOR HISTOGRAM COMMENTS

1. Reactor critical

2. Fuel conditioning

3. Hold for chemistry

4. Leak on main steam reheater

5. Condensate demineralizer pumps pulling ampheres

6. NRC holdpoint

7. Reactor trip

8. Putting main steam reheaters in service

9. Channel range calibration

10. Reactor at 95 percent, awaiting permission to go to 100 percent power

11. Reactor at 99 percent, reduced power to clear high steam flow bistables I

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SUMMARY

OF MAINTENANCE ACTIVITIES I

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9 4 9 3 MAINTENANCE

SUMMARY

(ELECTRICAL)

ELECTRICAL MAINTENANCE MONTILY StI1 MARY 04-10-88 Car 15t2. . . . U FUNC SYS A DDRESS. DATE. . . . DESCRIPTIM. . . . . . . . . . . . . . . . . . . . . . . . . . . . . CORRE B2923891 MTRB 047 0044 M/%/881-MTRS-047-C444-A,E.R.C.W. YALUE LIMITS THE MOTDR LEADS MD HOT BEG PULLED CACK AK ET LORKDG UN 1AA D/G ERCH SUPPLY PROPERLY DURIE REYIDUS MINTENANCE VALE. NEED TO MOVAT THE YEVE. IMEN THE THE MOTOR ROTOR HAD CDWTACTED YALYE WAS OlOED IT STOPPED AT 3A DPEN LEADS F4 SING TE MTUR TO BURN UP.

POSITIN. TE VALVE IS HOLDING tr 1BB KPLACED MOTOR (1-NTRB-47-44-8) MD D/G STI-ill 5 UTER TEST. PERFDRED MTM (PERATOR YALYE MALYSIS TEST. (WR B-292381).

B2929171 GENB 082 0001B %/11/881-GDB-082-00018-9,EnNPRDuhWHEN 188 D/C (1-G00-082-000181). TE P.ECMANICAL DRDOP IS GIVEN A IRI START AND REACHES IDLE MS DUT Of ADJUSTENT. ADESTED THE SPEID THE 11 EMIE IS NOT RUNNIE. AS HYDRALLIC GOVERIG DR00P TO % LOW BOTH SOON AS TE ENGIE IS INCREASE) 500 RPMS ENCIMES TO SHARE EQUAL LDAD, WITH THE TE 81 EMIE BEGAINS TO RECEIYE FUEL. 2301 CETROL IN THE "DFF" POSITION.

ADESTENT TO TE CENTERING COIL, WITH THE 2301 CONTEL IN THE "DW' PDSITION, WAS NOT PERFORMED DUE TO REGEST TUR TURTHER MALYSIS BY TE SYSTEMS ENGINEERING SECTIM. (WR8 B292917).

ELECTRICAL MAINTENANCE lEINTRY $lRIMARY 04-10 88 C0rr M2. . . . U FtrdC SYS A DDRE33. DATE. . . . DESCRIPTION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . CORRECTIVE A B75H131 FCV 042 0%8 OV28/981-fCV 062-0%8 ,EuMPRDu],VEYE IS OPEN CDIL !.13 TNT UP IN TE SEDE!ID YALVE AND CANNOT BE CLOSED FRDn itCR HS ON (1-FSV-442-0%8). REPLACED CGIL IN 1-5-5 YALVE IMS VERIFIED OPEN LOCELY SOLENDID VRVE MD TESTD VALVE FCR INVESTICATE AS REPAIR. PROPER OPERATION (UR4 B75%13).

B75 %14 1 BCTB 201 K /1B M/22/881-8CTB-201-DC /18-A,EuMPRDu,nP2GBKR DIRT, DU$T AND DRY GREASE IN CHARCING CHARGING $PRING fl0 TOR RUNS CONTT40$ flECHANISM PREVENTD PROPER RRATION.

WKW BKR IS PACKED IN MAKE REPAIR A3 CLEMD THE SPRING CHARCING FECHMI$n NECESSARY MD RETlftNED THE BREAKER TD SERVICE. (lat B-759did).

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4 9 9 MAINTENANCE

SUMMARY

(INSTRUMENTATION)

- - ,w- - --

INSTRUiUT MINTENANCE IRNT)R.Y SLRflARY 04-1 0-88

' CanP

' Ist2. . .". U FUNC $Y! A DME!! DATE. . . . DESCRIPTION . . . . . . . . . . . . . . . . . . . . . . . . . .

82479M 2 LCV 003 0173 03/23/88 2-LCV-003-0173-B.ExNPRDu3, UALUE LELLD A LEAK E3 LOCATD IN TE TW GAtKET ON NOT MMP OPEN CONTROLLER IS ESPGIDING THE PNEllMTIC RELAY. THIS MY MUE

~

TO TE RAfF IPEN/CLOSE $ WITCH IN MCR. DUE TO AGE. EPLACED RELAY WITH A NEW REGILATOR DUTPUT E3 IBICATING to PSIC ONE. PutFDED SI-75. OPEMTIDMS TO BUT PRES $WE GAUGE TO DIAPIRAGM II PERF05 $I-144.4. (WR$ B247911).

IRICATDIC ZERO.

R292473 1 IT 070 0098 05/14/881-fT-070-0098 ,Ei4FEDu,mP2u),FLCW THE CAUSE OF FAIL 15lE IS UMW. THE INDICATOR READS 2.5 GPM FLOW WITH CC3 TRAN!RITTER MS WT & TOLIRANCE HIGH FLOW ISOLATED. THRWGISUT TE EXTIRE MNGE. THE TRAN3MITTLR 23 ECALIBRATD TD DESIED TOLERANCE. (R$ B212473).

B292475 1 FT 070 0100 05/14/881-FT-070-0108 ,ENWRDu enP2m],Fl0W THE CAUSE F FAILDE I3 UNKHN. THE INDICATOR READS .5 GPM FLOW WITH CCS TRAN3RITTER MS Eli F TOLERANCE HIGH FLOW I!! LATED. THREJGET TE ENTIRE RANGE. THE TRAN!RITTER M3 ECALIMATD TO DESIRED TOLERANCE. (20 8292475).

INSTRUMDli MINTDtANCE MONTHLY StRRIARY 04-10-88

. . . C!IF M2. . . . U F UNC $YS A DDRESS. DATE. . . . DESCRIPTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . CDRECTIW ACTION. . . . . . . . .

8253259 2 FCU M3 00904 05/12/88 2-fCV-M3-00904 ,EuMPRDm3, VALE li!!! TION AND OPERATION DOES Nfli MTCH THAT OF CONTROLLER IN MIN CONTROL ROOM IWYESTIGATE AM REPAIR B247kie 2 FT M3 0155 03/30/88 2-FT-403-0155,ENMPRDu,ul00FR50. ton], WIT THE TRAH3MITTER MS IIIT OF TILERf'tCL M NO FLOW TH FLOW INDICATOR EAD3 35-40 HICH T)fulCHIRIT TV ENTIRE RANGE. THIS GPM. REPAIR AS NECE!!ARY MY HAVE BEEN DE TO AGE, CYCLING AND/OR EM. TE TRANSMITTER WAS CALIBRATED TO KSIRED TOLIRANCE PER 31-17.2. (WR0 B247494).

B267575 1 LT M3 0174 04/27/881-ti-003-0174-B Eul0CFR50.49m,mHfilDu,uP2 m3, LEVEL INDICATION FAILED LOW.

INVESTIGATI AND REPAIR At NECESSMY B267424 2 POS 003 0173 03/28/88 2-PO3-003-0173-8,CnNPRDu],THIS VILE THE CAUSC FAILUE IS UNKN[R0t. IT MY FAILD TO STROKE EMOTELY FOR 3I 144.1. HAYE BEEN DUE TO WEAR OR AGE. THE OLD POSITIIBIER WAS RDUCED WITH A EW OE, CALIBRATED AM UDITIED YALE STROKE.

ETIRED LOOP TO SGUICE PER SI-75. (WRt 8247442).

B290799 2 FT 070 0159C 05/0d/88 2-FT-070-4159C ,EmHPRDs3,2-FT-70-159C THE AMPLIFIER BOARD MS DETERMIED TO M W(1R.D NOT CALIDRATE iO WITHIM iOLERAHCE DEFECTIW. THIS MY HAVE KDI DUE TO DURING PDFORnMCE OF SI-201 EM. EPLACD TE AfrLIFIG BOMD WITH A NEW IFE MD CALIBRATED. YDtIFIED TEST POINT UOLTAGE AND INDICATOR FOR PMT.

(WRI B290799) (IMI-70.2) e

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MAINTENANCE

SUMMARY

(MECHANICAL) i

- _ _ , ~-

MECHMI(ML MINTENANCE fRBITit.Y SMMRY 04-10-88 CW M2. . . . U FUNC $Y1 ADDRESS. DATE. . . . DE3CRIPTI1DI . . . . . . . . . . . . . . . . . . . . . .. . . . . . . CORRECTIVE ACT 9200%4 2 YLV 047 4542A 05/02/88 2-YLV-047-0542A-A.EsNPRDu3,YALVE FAILED MD $MLL MENT IF DIRT 14fILD-UP.

SI-154.1 LEM RATE TEST LEM RATE MS EMOYD FLME CDYER, CLIMED AND 507.i. SCFN EPAIR OR EPLACE AS HEEDED. CHECKD SEAT!. SEATS LORD GOOD.

EIN$iELED FLANGE CDYER. (ING B200%d) 8247414 2 FCV 042 0073 03/23/88 2-FCV-042-00734,EmP2u,MPRDu3,lETICD NORML REAR. HDLE IN DIAPIEIAGM.

VEYC HAD A ED Ale GEG INDICATDC INSTALLD EW DIAPMAGM Alt STMD HUT LIGHT! DN MAIN CONTROL BOARD. CLDSD TO tiEM TO PEVENT STEM ROTATIK (WRt VEYE AND ATTEMPTD TO EDPEN. YENIFIED B247did)

YEYE IFEED BY DCREASD FLN INDICATION BUT DID MDT GET ED LIGHT.

B29%201 LCV 003 01M M/29/881-LCV-003-01M ,EmMPRDu,nP2m3,FIIJND DIAPHRAGM HAD A lELE IN II. EPLACED DIAPIEIAGM LEMING DURDG PERFRMMCE OF DIAPHRAGM ON YALYE AND STMD Hlif TO SI-75. RDLACE DIAPHRAGM AND ENSUIE NO STEM TD PREVENT STEM ROTATIDN. (IR4 LEMS AT ATHOSPHERIC YDIT. B29%20)-

875%83 2 PMP 070 0033 %/20/88 2-PMP-070-0033 ,EuMPRDu3, REPLACE D80ARD NORML EAR. 33tELD EW PACKING AND PMP PACKING PACKING GLMD. IiCPECTG SLEEVE, IT SHDED SOME EAR DUT NUT ENDUCN TD BE DETRIIUTAL. (WR4 B75%83).

F 4

MECHANICAL MAINTENANCE MONTHLY REPORT FOR MAY 1988 Unit 1

1. Instelled new valve at 1-VLV-62-521.

2. Cleaned 1A and 1C upper compartment coolers.

3. Repaired leak on 1B-B CCP speed increaser.

4. Completed mechanical inspection on IB-B D/G.

5. Cleaned and reinstalled reactor cooling pump No. I seal housing bolts.

6. Installed new valve at 1-FCV-43-10.

7. Cleaned IB-B upper compartment coolers.

8. Completed rebuilding of 20 valves on the chemical volume and control system.

9. Repaired 12 valves on glycol outage.

Unit 2

1. Completed maintenance innpection on 2B-B D/G.

2. Repaired three pressure safety valves with water to steam trim.

3. Reinstalled handrails on S/G #1, #2, #3, and #4,

4. Completed repair on 2B-B annulus vacuum fan.

5. Closed equipment hatch and blast doors.

6. Set biological shield.

7. Closed raceway hatch.

8. Installed new operator on 2-VLV-67-728.

9. Installed snubbers on condensate system.

10. Unplugged BAT to BIT line.

11. Pulled and reset center missile shield.

12. Removed and reinstalled various blind flanges.

13. Completed work on 2-VLV-72-507.

14 Installed new filter on 2A-A stator cooling water.

8 i

MECHANICAL MAINTFNANCE MONTHLY REPORT FOR MAY 1988 $

Unit 2 (Continued)

15. Installed new rupture disc on "B" boric acid evaporator.

16. Balanced reactor coolant pump No. 2.

17. Supported unit 2 startup. -

18. Repaired bus duct coolers.

19. Completed maintenance inspection on 2A-A D/G.

20. Installed new seal 0-rings on 2C No. 3 heater drain tank pump. ,

21. Installed new seal 0-rings on condenser booster pump.

22. Completed repair on 2A injection water pump discharge check valve.

23. Installed new sight glass on No. 3 heater drain tank.

24. Furmanited several valves.

25. Supported various sis.

Common

1. Completed repair on 0-PCV-14-168

2. Completed repair on "B" auxiliary air compressor.

3. Installed new booster pump on 0-RM-90-211.

Other

1. Continued closure of various CAQRs, CARS, DRs. etc.

d 1

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l MAINTENANCE

SUMMARY

(MODIFICATIONS)

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SUMMARY

OF WORK COMPLETED HODIFICATIONS - CURRENT STATUS MAY 1988 s

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Major Capital Projects:

PN7101: ECN 6388 - 500-kVA Switchyard Current Transformer Heaters i Workplan (WP) 12223 is in progress pending safe access to current transformers.

PN7102: ECN 5938 - Replace Feedwater Heaters 3 and 4 No work in progress at this time.

PN7105: ECN 5009 - Essential Raw Cooling Water (ERCW) Piping Changcout From Carbon Steel to Stainless Steel No additional pipo replacement is scheduled in the near futuro.

PN7108: ECN 6720 - Crano Consistency Pror_ ram Unit 2 polar crano modification is complete.

Postmodification testing (PMT) by Electrical Maintenanco is not complete. Unit 1 polar crano work started on July 6, 1987 and is approximately 98 percent complete.

Painting of blocks and limit switch weights romain to be completed. Auxiliary Building crano WP 12596 is in the

, approval cycle. Drawings have not been issued on the remaining cranes. WP 12596 is in nonwork status. Work is stopped pending resolution of budgetary problems.

PN7115: ECN 6 719 - Volumetric Intrusion Detection System ECN 6719 is still on hold. Security is dissatisfied with system operation. Security and DNE have not concluded discussions on resolution. Design is working on making the system functional. Lighting is not finished. Workplan chango for drainage is being written. Field Chango Roquest (FCR) 6645 for DNE changes is approved. Work is stopped pending resolution of budgetary problems.

PN7122: DCR 1373 Secondary Side No vork in progress at this timo.

ECN 5657 - Installation of Moisturo Separator Rohoater (MSR)

Drain Valves Work is complete.

Major Capital Projects (cont.):

ECN 5841 - Hot Shop Fire Protection / Evacuation Alarm -

WP 12637 All fieldwork for evacuation alarm is completo. Awaiting Work Roquest (WR) B240406 to be worked to restart fans to do functional test on fire protection.

PN7123: ECNs 5938. 6305. 6571 - Replace Feedwater Heaters 1 and 2.

Units 1 and 2 and Eroded Pipe Modifications are complete.

PN7130: DCR 1156 - Post Accident Monitoring This work is now scheduled for unit 1 by unit 1 cycle 4 (U1CA) and unit 2 by unit 2 cycle 4 (U2C4).

PN7132: DCN 0026 - SewaRo Treatment Facility and Civil Upgrado City of Soddy-Daisy will be responsiblo for interface work on site, lift station, and pipelino betwoon Sequoyah Nuclear Plant and Highway 27. WP 0026-01 is in approval cycle. DCN is being revised to includo the Solar Building dischargo effluent to Soddy-Daisy interface.

PN7136: ECN 6259 - MSR Tube Bundle Replacement ECN is completo except for PMT and incervico leak test. Leak checks will bo performed during system heatup. Unit 2 leak checks are complete.

PN7161: ECN 5855 - Replacement of Doors A56 and A57 Functional testing is complete.

PN1181: DCR 1898 - ECNs 6832 and 6596 - Dry Activo Waste (DAW)

Building Electrical interface werk is completo. Workplan closure hold for Instrument Maintenanco (WP 124 78) . Electrical Maintenance (WP 12612), checks and update of Solo by Operations, and Operations (WP 12477) pending RHSI-1 reviolon.

Ms3or Capital Projects (cont.):  ;

Significant Items:

PN7199: Miscellaneous Activities Under $100.000 ,

This is for various work ceders prepared for work under

$100,000 total site cost. This work was done as manpower resources were available that did not impact unit 2 restart.

The following major significant items are under Operation and Maintenance Expense (D&M).

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1. Fuse Program Work ECW 5880 - Work is complete.

2. Cable Ampacity Program ,

Unit 1 Cable Ampacity Program is complete.

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Other Items:

ECW 5111 - Provide Permanent Power to Manholes 42-46 Electrical conduit and wiring installation for manholes 44-46 is ,

complete according to WP 12262. Manholes 42 and 43 are being hald for information from DNE on power cable routing and terminations. FCR [

4572R1 was sent to DNE and was logged in, but it was not sent to the responsible ensinner. Manholes 42-46 will be worked by FCR 4572R1. [

This item is not considered unit 2 restart by DNE, and they will not l authorize the engineer to do the necessary work to obtain pull cards or drawings for manholes A2-46. FCR 4572R2 will be written to  !

supersede 4572R1 for cor Ett snd cable routing for nenholes 42-46.

ECW 5435 - Fire Doors No rark is in progress at this time.

ECN 5503 - Evacuation Alarms O&PS/ Fire Detection O&PS i No work in progress at this time.

WP 12664 - Work is complate.

ECN 5552, - Condensate Demineralizer Modifications and Migh Crud Filter Upgrade to higher range instrumentation for condensate demineralizer system neutralization and nonreclaimable waste pumps.

WP 5552 Work La complete.

WP 5552 Install flow recorder, write workplan activity, work started June 1, 1988.

ECN 5609 - Evacuation Alarm / Fire Detection Valve 26-290 WP 12387 is 90 percent complete. No work is in progress at this timu.

ECN 5609 - Alteration to the Makeup Water Treatment Plant I

i WP 12576 - Work is in process and approximately 75 percent complete.

Hold for instrument tab (478601-92) revision (now identift:ation numbers), and Electrical Maintenance to perform breaker tests.

t WP 12633 - Work is in process and approximately 60 percent complete.

l Hold for instrument tab (47B601-928) set point revisions.

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Other Items (cont.):

WP 12731 - WP is in work and is approximately 40 percent complete.

Hold for instrument tab (47B601-928) set points.

WP 12684 - WP in wcrk, approximately 70 percent complete. Hold for instrument tab (47B601-928) set points.

WP 12665 - WP is being worked and is 95 percent complete.

WP 12682 - WP is being worked and is 80 percent complete.

ECN 5626 - Containment Ladders, Unit 1 Modifications needs additional design information to complete. DNE needs to issde all drawings listed on this EC... Work has not begun because of this holdup.

ECN 5726 - CAQR SQP870478 - Reroute Sense Line Piping for Train Separation to Panels 2-L-58 and 2-L-68 Fi11dwork is complete. In-service leak check is complete.

ECN 5841 - Hot Shop Fire Detection WP 12360 is complete.

ECN 5935 - Correct Power Block Lighting Deficiencies WP 12437 is complete. WP 12275 is in work. Modifications needs DNE to provide missile protection requirements for our excavations and the USQD. WP 5435-01 has been written to install security grills and gratings. Approval of WP 5935-01 was delayed for drawing revision.

Drawing has been received and workplan is in the approval cycle.

ECN 6057 - Cable Tray Covers This activity is complete for the unit 2 restart. The only remaining work is the unit I annulus and this will be completed prior to June 30, 1988.

ECN 6082 - Vent for Boric Acid Tank (BAT)

Work is complete.

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ECN 6196 - Pressurizer Hangers and Valves PMT is scheduled for unit I restart. Remaining unit 2 work is scheduled for U2C3 refueling outage.

ECN 6205 - Replacement of Instrument Loop Power Supply Fuses Complete.

ECN 6357 - Essential Raw Cooling Water (ERCW) Roof Access and Rails for Security Equipment WP 12238 is in work and is approximately 20 percent complete.

ECN 6388 - Hydrogen Monitors in Switchyard Workplan 12223, installation of hydrogen analyzers at 500-kV switchyard, is 75 percent complete.

ECNs 6402 (Unit 1) and 6439 (Units 1 and 2) - Pressurizer InstrJmontation Relocation In-service tects will be performed when the system is brought up to temperature and pressure.

ECN 6429 - Component Cooling Heat Exchanger B Replacement Plate head exchanger and frame is complete. Hangers and pipe which can be installed prior to outage is in work. Workplan to remove old heat exchanger is in review cycle. DNE procuring the remaining needed piping material. Estimated completion date for nonoutage work is during the month of June 1988.

ECN 6455 - Upgrade CU-3 Box Battery Packs WP 12295 has been issued. Hodifications are complete for all CU-3 boxes. Site Security still needs to perform SI-630 on DNE remaining channel before workplan can be closed.

ECNs 6491 and 6534 - Essential Raw Cooling Water (ERCW) Supports All restart work is complete. A workplan to remove previously installed piping was approved and will be worked as resources permit.

e o Other Items (cont.):

ECN 6543 - Install Public Safety Access Portals and Modify Entrance Road -

Work is being held pending the release of drawings from DNE.

ECN 6601 - Removal of Unit 1 Emergency Cas Treatment System (EGTS)

Backdraft Dampers PMT remains to be completed by the Mechanical Test Section. Fieldwork is ccmplete.

ECW 6610 - Modify Air Return Fan Supports Unit I work is in process.

ECN 6631 - Modify Snubbers Unit 2 work is complete.

ECN 6689 - Relocation of Main Steam Power Operated Relief Valves (PORV)

All work is complete for unit 2. Work on unit I has started.

ECN 6698 - Repull 120-Volt Cables Unit 2 is complete. Unit 1 is 90 percent complete and held by ECN 6742. This ECN should be completed prior to unit i restart.

ECN 6706 14 Support Enhancement / Lost Calculations Repairs continue on unit 1. This project has been combined with the calculation regeneration project for unit 1. Unit 2 work is complete and workplans are closed. There are 25 modifications in work with 46 having been completed. In addition, 82 maintenance items are in progress with 293 complete.

ECN 6739 - Alternate Analysis All unit 1 modification work has been completed. Review and closure has begun. Work is in progress on the maintenance items.

ECN 6742 - Install Fuses in Radiation Monitor Power Supply Circuits The workplan is complete for unit 2. Unit 1 is in work.

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Other Items (cont.):

ECN 6761 - East Valve Room (EVR) Blowout Panels Implementation of unit I work is progressing as resources are available. Unit 2 work is complete.

ECN 6784 - Documentation to Show Pipe Class Breaks Final closure is awaiting a revision to AI-19 deleting requirements to mark shift supervisor drawings.

ECN 6815 - Installation Power Circuit Breaker Install 500-kV power circuit breaker and associated equipment for bay 1. Retire 161-kV PCB and associated equipment. A total of 10 workplans will be required. Foundations and conduit installation (WP 12654) are complete. WP 12740 for lighting, drain pipe, and surface ground mat is 70 percent complete. WP 12739 for the structural steel installation is 90 percent complete. WP 6815-02 is 75 percent complete. WP 6815-01 and WP 6815-03 are 60 percent complete. WP 6815-04 and WP 6815-05 for the electrical control board, main relay boards, and the communications room are in work. WP 6815-06 for tne addition of the Franklin solid state relay cabinets has been approved. The estimated dates to have the Watts Bar line No.

1, and the Franklin line energized is by June 30, 1988. The estimated date to have the 161-kV AEDC line and equipment removed is by mid-August 1988.

ECN 6860 - Control Room Bullet Resistivity - DCR 2268 - ECN 6860 WPs 12602 and 12604 are field complete. WP 12603 is held for disposition of CAQR 880183. WPs 12605 and 6860-01 are held for material on Contract 74014A. Essentially all work is complete except for pull handles, replacement of door closures, rework of one lockset, and replacement of one electric hinge. Estimated date of completion is June 30, 1988.

ECN 7257 - Install All New Cooling Colls in the Reactor Building Lower Compartment Coolers l

Lower compartment cooler and coils have been replaced.

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{ ECN 7078 - Install Hangers - Main Steam Piping Complete except for final inspections during heatup.

DCN X00006A - Remove Hydrogen Analyzers Tubing The workplan lacks PMT (SI-219).

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I Other Items (cont.): l ECN 7078 - Install Hangers - Main Steam Piping Complete except for final inspections during heatup.

DCN 200018B - Install Needle Valve for Hydrogen Analyzers The workplan lacks PMT (SI-219).

DCN 70 - Hydrogen Analyzer Check Valves The workplan lacks PMT (SI-219).

DCN 192 - Pressurizer Loop Seal Work is complete. Workplan in closure cycle.

Instrumentation Verification Program For unit 2, there have been 953 discrepancies issued to MODS to date with 476 not required for restart. All discrepancies required for restart have been completed; 69 noncestart discrepancies are open.

For unit 1, there have been 532 discrepaneles issued to MODS to date with 218 not required for restart. Of 314 required for restart, 10 remain open and are being worked. Estinated date to be completed with all discrepancies which pertain to unit I restart is June 17, 1988.

DCN 224 - RHR Slope Rowork Train A complete, Train B needs outage.

ECN 7318 - Capillary Tray Hanger Rowork In work.

ECN 7345 - Four Valve Manifold Shims Complete.

DCN 27 - Double Isolation Valves In work, DNE procuring material.

DCN 206 - RSWI Hangers Complete.

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I Other Items (cont.):

DCN 214 - AFW Tap Rotation Complete, Instrument Maintenance to test.

DCN 242 - Sense Line Hangers In work.

ECN 6596 - WP 12402 - Workplan is closed.

WP 12477 - Requires Instrument Maintenance calibration and checkout of area radiation monitor and air compressor.

WP 126'.2 - Complete. Closure in process. SOIs are complete. SI-743 is in the process of being updated by Electrical Maintenance.

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OFr' SITE DOSE CALCULATION MANUAL CHANGES REVISION NO. 19 l

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r-SE000YAH NUCLEAR PLANT OFFSITE DOSE CALCULATION MANUAL EFFECTIVE PAGE LISTING REVISION 19 E.agg a

-Revision Listing of Dates of Revisions Revision 19 Table of Contents Page 1 through 2 Revision 17 Table of Contents Page 3 through 4 Revision 19 Pages 1 through 34 Revision 17 Page 35 Revision 19 Page 36 through 48 Revisien 17 Page 49 Revision 19 Page 50 through 68 Revision 17 Page 69 through 85 Revision 19 EPL-1 1157c

SEOUOYAH NUCLEAR PLANT OFFSITE DOSE CALCULATION MANUAL LIST OF TABLES REVISION 19 Page 1.1 EXPECTED ANNUAL ROUTINE GASEOUS RELEASES FROM O!E UNIT AT SEQUOYAH NUCLEAR PLANT 38 1.2 BASIC RADIONUCLIDE DATA 39 1.3 JOINT PER^ENTAGE FREQUENCIES OF WIND DIRECTION AND WIND SPEED FOR DIFFERENT STABILITY CLASSES 41 1.4 SQN - 0FFSITE RECEPTOR LOCATION DATA 49 1.5 DOSE FACTORS FOR SUBMERSION IN NOBLE GASES 50 1.6 NUCLIDE SPECIFIC TRANSFER DATA 51 1.7 INTERNAL DOSE FACTORS - INFANT THYROID 53 1.8 EXTERNAL DOSE FACTORS FOR STANDING ON C0!GAMINATED GROUND 54 2.1 INGESTION DOSE FACTORS 56 2.2 FISH CONCENTRATION FACTORS 60 2.3 RECREATION DOSE FACTORS 62 2.4 PUBLIC WATER SUPPLY INFORMATION 66 2.5 FISH HARVEST DATA 67 2.6 RECREATION USAGE DATA 68 3.1 RADIOLOGICAL EINIRONMENTAL MONITORNG PROGRAM 69 3.2 ENVIRONMENTAL RADIOLOGICAL MONITORING PROGRAM SAMPLING 73 3.3 SEQUOYAH NUCLEAR PLANT THERM 0LUMI!ESCENT DOSIMETER 75 I

LOCATIONS 3.4 MAXIMUM VALUES FOR THE LOWER LIMITS OF DETECTION (LLD) 77 TOC - 3 1157c 5

SEQUOYAH NUCLEAR PLANT OFFSITE DOSE CALCULATION MANUAL LIST OF FIGURES REVISION 19 page 1.1 PLUME DEPLETION EFFECT FOR GROUND LEVEL RELEASES 79 1.2 RELATIVE DEPOSITION FOR GROUND LEVEL RELEASES 80 1.3 GASEOUS RADWASTE TREATMENT SYSTEM 81 3.1 RADIOLOGICAL EtTVIRONMENTAL SAMPLING LOCATIONS - WITHIN 82 1 MILE OF PLANT 3.2 RADIOLOGICAL ENVIRONMENTAL SAMPLING LOCATIONS - WITHIN 83 1 TO 5 MILES OF PLANT 3.3 RADIOLOGICAL ENVIRONMENTAL SAMPLING LOCATIONS - 84 GREATE9. THAN 5 MILES OF PLANT TOC - 4 1157c

SQN ODCM  :

Page 35 of 85 Revision 19 3.0 Radiological Environmental Monitorina 3.1 Monitorina Program An environmental radiological monitoring program shall be conducted in accordance with Technical Specification 3.12.1. The monitoring program described in Tables 3.1, 3.2, and 3.3, and in Figures 3.1, 3.2 and 3.3 shall be conducted. Results of this program shall be l reported in accordance with Technical Specifications 6.9.1.6 and 6.9.1.7.

The atmospheric environmental radiological monitoring program shall consist of monitoring stations from which samples of air particulates and atmospheric radioiodine shall be collected.

The terrestrial monitoring program shall consist of the collection of vegetation, milk, soil, ground water, drinking water, and food l crops. In addition, direct gamma radiation levels will be measured in the vicinity of the plant.

The reservoir sarpling program shall consist of the collection of samples of surface water, sediment, clams, and fish.

Deviations are permitted from the required sampling schedule if specimens are unobtainable due to hazardous conditions, sample unavailability, or to malfunction of sampling equipment. If the latter, every effort shall be made to complete corrective action prior to the end of the next sampling period.

3.2 Detection Capabilities Analytical techniques shall be such that the detection capabilities listed in Table 3.4 are achieved.

3.3 Interlaboratory Comparison Program Analyses shall be performed on radioactive materials supplied as part of an Interlaboratory Comparison Program which has been approved by the NRC. A summary of the results obtained in the intercomparison shall be included in the Annual Radiological Environmental Operating Report (or the EPA program code designation may be provided).

If analyses are not performed as required corrective actions taken to prevent a recurrence shall be reported in the Annual Radiological Environmental Operating Report.

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9 SQN ODCM Page 49 of 85 Revision 19 Table 1.4 SQN - 0FFSITE RECEPTOR LOCATION DATA DIST ELEV X/Q D/Q POINT SECTOR (m) (m) (s/m3) (1/ma y,_

1 Land Site Boundary N 950 -6. 5.12E-06 1.29E-08 2 Land Site Boundary NNE 2260 -6 1.93E-06 5.28E-09 3 Land Site Boundary NE 1910 -6, 2.32E-06 6.33E-09 4 Land Site Boundary ENE 1680 -6. 1.12E-06 2.64E-09 5 Land Site Boundary E 1570 -6. 7.10E-07 1.46E-09 6 Land Site Boundary ESE 1460 -6. 7.91E-07 1.58E-09 7 Land Site Boundary SE 1460 -6. 9.14E-07 2.41E-09 8-Land Site Boundary SSE 1550 -6. 1.34E-06 3.23E-09 9 Land Site Boundary -

S 1570 -6. 2.37E-06 4.18E-09 10 Land Site Boundary SSW 1840 -6. 4.51E-06 9.26E-09 11 Land Site Boundary SW 2470 -6. 1.38E-06 2.63E-09 12 Land Site Boundary WSW 910 -6. 2.93E-06 3.86E-00 13 Land Site Boundary W 670 -6 3.63E-06 3.74E-09 14 Land Site Boundary kani 660 -6. 2.49E-06 2.44E-09 15 Land Site Boundary NW 660 -6. 2.25E-06 3.67E-09 16 Land Site Boundary NNW 730 -6. 3.95E-06 6.59E-09 17 Resident N 1370 0. 2.93E-06 18 Resident 2710 0.

7.10E-09l NNE 1.49E-06 3.88E-09 19 Resident, Garden NE 2140 15. 1.98E-06 5.21E-09 20 Resident ENE 2290 0. 7.13E-07 1.57E-09 21 Resident E 1790 8. $.85E-07 1.18E-09 22 Resident ESE 1790 46. 5.86E-07 1.14E-09 23 Resident SE 1680 0. 7.42E-07 1.92E-09

?4 Resident, Garden SSE 2210 46, 7.99E-07 1.79E-09 25 Resident S 2020 0. 1.65E-06 2.75E-09 26 2esident, Garden SSW 2290 0. 3.31E-06 6.38E-09 27 Resident SW 3010 0. 1.04E-06 1.88E-09 28 Resident WSW 1140 8. 2.00E-06 2.67E-09 29 Resident W 1750 47. 8.53E-O/ 7.82E-10 30 Resident, Carden WNW 1750 12, 5.71E-07 4.98E-10 31 Resident NW 1140 11. 1.25E-06 1.50E-09 32 Resident, Garden NNW 800 0. 3.42E-06 5.67E-09 33 Garden N 1680 0. 2.20E-06 5.10E-09 34 Garden NNE 3010 0. 1.28E-06 3.24E-09 35 Garden E 2630 9. 3.38E-07 6.14E-10 36 Carden ESE 1980 29. 5.08E-07 9.57E-10 37 Garden SE 3010 47, 3.19E-07 7.16E-10 38 Garden S 2290 0. 1.38E-06 2.22E-09 39 Garden SW 3660 24. 7.96E-07 1.34E-09 40 Garden WSW 1680 0. 1.16E-06 1.43E-09 41 Garden W 1830 0. 8.02E-07 7.26E-10 42 Garden NW 1180 11 1.19E-06 1.42E-09 43 Milk Cow Adult N 4120 0. 6.18E-07 1.10E-09 44 Milk Cow Adult NE 6750 47. 3.94E-07 7.03E-10

. 45 Milk Cow Adult kaSJ 1750 12. 5.71E-07 4.98E-10 46 Milk Cow Adult NW 1980 5. 5.61E-07 6.09E-10 1157c

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lABLE 3.1 (Sheet 1 of 4)

RAD 1010GICAL ENVIRONMENTAL MONITORING PROGRAM Exposure Pathway Saryling and Type and Frequency and/or Sanple Sample tocations* Collection Frequency of Analysis

1. AIRBORNE

a. Particulates 4 samples from locations Continuous sampler Analyze for gross beta (in different sectors) at operation with sample radioactivity > 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or near the site boundary collection once per following filter change.

(LM 2, 3, 4, and 5) 7 days (more frequently Perform ganma isotopic if required by dust analysis on each sample loading) if gross beta > 10 times yearly mean of control sample.

Composite at least once per 31 l days (by location for ganma scan) 4 samples from conununities approximately 6-10 miles distance from the plant (PM 2, 3, 8, and 9) 4 samples from control locations grt-ater than 10 miles from the plant (RM 1, 2, 3, and 4)

b. Radioiodine Sanples from same locations Coritinuous sampler l'i l at least once per as air particulates operation with tilter 7 days collection once per 7 days

c. Soil Sanples from same locations Once per year Ganma scan, 8 %r, '%r as air particulates once each year l

2. DIRECT RADIA110N 2 or more dosimeters placed Dnce per 92 days Ganma dose at least at 11 of the air particulate once per 92 days sampling stations (LM-3, LM-4, LM-5, PM -2, PM-3, PM-8, PM-9, RM-1, RM-2, RM-3, and RM-4) 2 or more dosimeters placed at each of at least 30 other locations.

(Figures 3.1, 3.2, and 3.3) l

+5 ample locations are listed in Tables 3.2 and 3.3 and shown on Figures 3.1, 3.2, and 3.3.

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TABLE 3.1 (Sheet 2 of 4)

RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM Exposure Pathway Sanpling and Type and frequency and/or Sanole Sample locations

• Collection Frequency of Analysis

3. WATERBORNE

a. Surface TRM 497.0 Collected by automatic Gama scan of each 1RM 483.4 sequential-type sampler ** composite sample. l TRM 473.2 with composite samples Conrosite for tritium collected over a period analysis at least of 5 32 days once per 92 days

b. Ground 1 sanple adjacent to At least once per 92 Gross beta, ganina scan plant (location W-6) days and tritium analysis 1 at least once per 92 days I 1 sonple from ground water source upgradient

c. Drinking 1 sanple at the first Collected by automatic Gross beta and ganina potable surface water sequential-type sampler ** scan of each composite l

l supply downstream from with composite sample samp)c. Comnasite for the plant (TRM 413.0) collected over a period tritium, soir, Sr at least

, of 5 31 days once per 92 days l 1 sanple at the next 2 Grab sample once per 31

! downstream potable surface days water suppliers (greater than 10 miles downstream)

(1RM 470.5 and 465.3) l 2 sanples at control- Samples collected by locations (TRM 497.0 au'.omatic sequential-and TPfi 503.8) type sampler with composite panple collected over a period of $ 31 days

d. Sediment ikM 496.5 At least once per 184 GanviL1 scan of each l TRM 483.4 days sanple 1RM 480.8 1RM 472.8 l 75anple locations are listed in Tables 3.2 and 3.3 and shown on f igures 3.1, 3.2 and 3.3. .

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• • Samples shall be collected by collecting an aliquot at intervals not exceeding E hours.

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TABLE 3.1 (Sheet 3 of 4)

RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM -

Exposure Pathway Sampling and Type and Frequency and/or Sample Sanple locations

• Collection Frequency of Analysis

e. Shoreline TRM 485 At least once per 184 Ganma scan of each Sediment TRM 478 days sanple IRM 417 l

4. INGESTION

a. Milk 1 sample from milk producing At least once per 15 days Ganma isotopic and animals in each of 1-3 areas 1211 analysis of each indicated by the cow census l sample. * *S r, So5r once where doses are calculated per quarter to be highest. If samples are not available from a i

milk animal location, doses to that area will be estinuted by projecting the doses from concentrations detected in milk from other sectors or by sanpling -

j vegetation where milk is not available (Table 3.1, 4.d)

At least I sanple from a .

control location.

. b. Fish 1 sample each for Nickajack, At least once per 184 Ganma scan on edible Chickamauga, and Watts Bar days. One sanple of portion Reservoirs each of the following species:

i Channel Catfish Crappie Smallmouth Buffalo l ayg m o

=Sanple locations are listed in Tables 3.2 and 3.3 and shown on Figures 3.1, 3.2, and 3.3. o%E c ~

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TABLE 3,1 (SheGt 4 Gf 4)

• RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM Exposure Pathway SanMing and Type and Frequency and/or Sample Sample locations

• Collection Frequency of Analysis

c. Invertebrates TRM 496.5 At least once per Gamma scan on edible (Asiatic Clams) TRM 483.4 184 days. portion IRM 480.8

d. Food Products I sanple each of principal At least once per 3E5 Gansna scan on edible food products grown at days at time of portion private gardens and/or harvest. The types fanns in the inmediate of foods available vicinity of the plant. for sampling will vary.

following is a list of typical foods which may be available:

Cabbage and/or lettuce Corn Greeh Beans Potatoes lomatoes l e. Vegetation I sanple from up to three At least once per 31 days Ganma scan at least locations of milk-producing once per 31 days.

animals where a sanple of * *Sr and 'OSr milk is not available and analysis and least at each air particulate once per 92 days station aSanple locations are listed in Tables 3.2 and 3.3 and shown on Figures 3.1, 3.2, and 3.3.  ;

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t a SQN ODCM Page 73 of 85 Revision 19 TABLE 3.2 SEQUOYAH NUCLEAR PLANT Environmental Radiological Monitoring Program Sampling Locations Map Approximate Indicator (I)

Location Distance or Samples Number a Station Sector (Miles) Control (C) Collectedb 2 LM-2 N 0.8 I AP, CF, S, V 3 LM-3 SSW 1.2 I AP, CF, S. V 4 LM-4 NE 1.5 I AP, CF, S, V 5 LM-5 NNE 1.8 I AP, CF, S. V 7 PM-2 SW 3.8 I AP, CF, S, V 8 PM-3 W 5.6 I AP, CF, S. V 9 PM-8 SSW 8.7 I AP, CF, S, V 10 PM-9 WSW 2.6 I AP, CF, S. V 11 RM-1 SW 16.7 C AP, CF, S. V 12 RM-2 NNE 17.8 C AP, CF, S, V 13 RM-3 ESE 11.3 C AP, CF, S. V

. 14 RM-4 kaN 18.9 C AP, CF, S. V 15 Farn B NE 43.0 C M, V 16 Farm C NE 16.0 C M, V 17 Farm S NNE 12.0 C M, V 18 Farm J WNW 1.1 I M. V 19 Farm H" ttW 1.2 I M, V, We 20 Farm EM N 2.6 I V 21 Farm Br SSW 2.2 I V 24 Well No. 6 NNE 0.15 I W j 31 TRMd 473.0 --

11.5e I PW (C.F. Industries) 32 TRM 470.5 --

14.00 I PW (E.I. DuPont) 33 TRM 465.3 --

19.28 I PW (Chattanooga) 34 TRM 49 7.0 --

12.5e Cd sw 35 TRM 503.8 --

19.3e C PW l

(Dayton) 36 TRM 496.5 --

12.00 C CL, SD 37 TRM 485.0 --

0.5e C SS 38 TRM 483.4 --

1.10 I CL, SD, SW l 39 TRM 480.8 --

3.70 I CL, SD 40 TRM 477.0 --

7.50 I SS 41 TRM 473.2 --

11.30 I SW 42 TRM 472.8 --

11.7e I SD 44 TRM 478.8 --

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l SQN ODCH Page 74 of 85 Revision 19 TABLE 3.2 (Continued)

SEQUOYAH NUCLEAR PLANT Environmental Radiological Monitoring Program Sampling Locations Map Approximate Indicator (I)

Location Distance or Samples Number _a Station Sector (Miles) Control (C) Collectedb 45 TRM 425-471 -- --

I F (Nickajack Reservoir) 46 TRM 471-530 -- --

I F (Chickamauga Reservoir) 47 TRM 530-602 -- --

C F (Watts Bar Reservoir)

a. See figures 3.1, 3.2, and 3.3 *

b. Sample Codes AP = Air particulate filter CF = Charcoal filter CL = Clams F = Fish M = Milk PW = Public water R = Rainwater S = Soil SD = Sediment SS = Shoreline sediment SW = Surface water V = Vegetation W = Well water

c. A control for well water,

d. TRM = Tennessee 111ver Mile.

e. Distance from plant discharge (TRM 484.5)

f. Surface water sample also used as a control for public water.

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SQN ODCM Page 75 of 85 Revision 19 Table 3.3 SEQUOYAH NUCLEAR PLANT Thermoluminescent Dosimeter Locations Map Approximate Onsite (On)a Location Distance or Number Station Sector (Miles) Offsite (Off) 3 SSW-1A SSW 1.2 On 4 NE-1A NE 1.5 On 5 NNE-1 NNE 1.8 On 7 SW-2 SW 3.8 Off 8 W-3 W 5.6 Off 9 SSW-3 SSW 8.7 Off 10 WSW-2A WSW 2.6 Off 11 SW-3 SW 16.7 Off 12 NNE-4 NNE 17.8 Off 13 ESE-3 ESE 11.3 Off 14 WNW-3 WN'n' 18.9 Off 49 N-1 N 0.6 On 50 N-2 N 2.1 Off 51 N-3 N 5.2 Off 52 U-4 N 10.0 Off 53 NNE-2 UNE 4.5 off 54 NNE-3 NNE 12.1 Off 55 NE-1 NE 2.4 Off 56 NE-2 NE 4.1 Off 57 ENE-1 ENE 0.4 On 58 ENE-2 ENE 5.1 Off 59 E-1 E 1.2 On 60 E-2 E 5.2 Off 61 ESE-A ESE 0.4 On 62 ESE-1 ESE 1.2 On 63 ESE-2 ESC 4.9 Off 64 SE-A SE 0.4 On 65 SE-B SE 0.4 On 66 SE-1 SE 1.4 On 67 SE-2 SE 1.9 On 68 SE-4 SE 5.2 Off 69 SSE-1 SSE 1.6 On l 70 SSE-2 SSE 4.6 Off 71 S-1 S 1.5 On 72 S-2 S 4.7 Off 73 SSW-1 SSW 0.6 On 74 SSW-2 SSW 4.0 Off

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O' SQN ODCM Pago 76 of 85 Revision 19 Table 3.3 (Continued)

SEQUOYAH NUCLEAR PLANT Thermoluminescent Dosimeter Locations Map Approximate Onsi.a (On)a Location Distance or Number Station Sector (Miles) Offsite (Off) 75 SW-1 SW 0.9 On 76 WSW-1 WSW 0.9 On 77 WSW-2 WSW 2.5 Off 78 WSW-3 WSW 5.7 Off 79 WSW-4 WSW 7.8 Off 80 WSW-5 WSW 10.1 Off 81 W-1 W 0.8 On 82 W-2 W 4.3 off 83 WNW-1 WNW 0.4 On 84 WNW-2 WIN 5.3 Off 85 NW-1 NW 0.4 On 86 IN-2 NW 5.2 off 87 NIN-1 NIN 0.6 On 88 NNW-2 NIN 1.7

• On 89 NIN-3 NIN 5.3 Off 4

a. TL0s designated onsito are those located two miles or less from the plant.

TLDs designated offsite are those located more than two' miles from the plant.

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SQN ODCM Page 77 of 85 Revision 19 Table 3.4 (1 of 2)

MAXIKUM VALUES FOR THE LOWER LIMITS OF DETECTION.(LLD)a,c Airborne Particulate Analysis Water or Gas Fish Milk Food Products Sediment (pCi/L) (pCi/L) (pC1/m3) (pCi/kg, wet) (pCi/L) (pCi/kg, wet) (pci/kg. dry) gross beta 4 1 X 10-2 N.A. N.A. N.A. N.A.

H-3 2000 N.A. N.A. N.A. N.A. N.A.

Mn-54 15 N.A. 130 N.A. N.A. N.A.

Fe-59 30 N.A. 260 N.A. N.A. N.A.

Co-58,60 15 N.A. 130 U.A. N.A. N.A.

2n-65 30 N.A. 260 N.A. N.A. N.A.

Zr-95 30 N.A. N.A. N.A. N.A. N.A.

Nb-95 15 N.A. N.A. N.A. ,

N.A. N.A.

1-131 lb y x 10-2 N.A. 1 60 N.A.

Cs-134 15 5 X 10-2 130 15 60 150 Cs-137 18 6 X 10-2 150 18 80 180 Ba-140 60 N.A. N.A. 60 N.A. N.A.

La-140 15 N.A. N.A. 15 N.A. N.A.

TABLE NOTATION a

The LLD is the smallest concentration of radioactive ma'terial in a sample that will be detected with 95% probability with 5% probability of falsely concluding that a blank observation represents a "real" signal.

For a particular measurement system (which may include radiochemical separation):

LLD = 4.66 sb E V 2.22 Y exp(-Kat)

~ ~" ~

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SQN ODCM Page 78 of 85 Revision 19 Table 3.4 /.1 of 2)

MAXIMUM VALUES FOR Tile LOWER LIMITS OF DETECTION (LLD)a,c TABLE NOTATION (continued)

Where:

LLD is the "a priori" lower limit of detection ac dafined above (picoeurie per unit mass or volume),

sb is the standard deviation of the background counting rate or of the counting rate of a blank sample as appropriate (counts per minute),

E is the counting ef ficiency (counts per transformation),

V is the sample size (units of mass or volume),

2.22 is the number of transformations per minute per picoeurie, Y is the fractional radiochemical yield (when applicable),

k is the radioactive decay constant for the particular radionuclide, and at is the elapsed time between sample collection (or end of the sample collection period) and time of counting (for environmental i

samples, not plant offluent samples).

The value of s3 used in the calculation of the LLD for a detection system shall be based on the actual observed variance of the background counting rate or of the counting rate of the blank samples (as appropriate) rather than on an unverified theoretically predicted variance. In calculating the LLD for a radionuclide determined by gamma-ray spectrometry, the background shall include the typical contributions of other radionuclides normally present in the samples (e.g. , potassium-40 in milk samples). Typical values of E, V, Y, and at shall be used in the calculations.

b The LLD for analysis of drinking water and surface water samples shall be performed by gamma spectroscopy at approximately 15 pCi/L.

If levels greater than 15 pCi/L are identified in surface water samples downstream from the plant, or in the event of an unanticipated release of I-131, drinking water samples will be analyzed at a LLD of 1.0 pCi/L for I-131.

e f other peaks which are measurable and identifiabic, together with the radionuclides in Table 4.12-1, shall be identified and reported.

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.'t (6 e TENNESSEE VALLEY AUTHORITY Sequoyah Nuclear Plant

, P. O. Box 2000 Soddy-Daisy, Tennessee 37379 June 13, 1988 Nuclear Regulatory Connission Office of Management Information and Program Control Washington, DC 20555 Gentlemen:

r Enclosed is the May 1988 Monthly Operating Report to NRC for Sequoyah Nuclear Plant.

Very truly yours, TENNESSEE VALLEY AUTHORITY S /J. Smith Plant Manager Enclosure ec (Enclosure):

Director, Region II INPO Records Center Nuclear Regulatory Connission Suite 1500 Office of Inspection and Enforcement 1100 Circle 75 Parkway Suite 3100 Atlanta, Georgia 30339 (1 copy) 101 Marietta Street Atlanta, Georgia 30323 (1 copy) Mr. K. M. Jenison Resident NRC Inspector Director Office of Inspection O&PS-2, Sequoyah Nuclear Plant and Enforcement Nuclear Regulatory Commission Washington, DC 20555 (12 copies)

Director Office of Special Projects 4350 East West Highway. EW 322 Bethesda, Maryland 10814 (10 copies)

Mr. T. Marston Electric Power Research Institute P. O. Box 10412 Palo e,ito, California 94304 (1 copy)

An Equal Ooportunity Employer