ML20244E318

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Monthly Operating Repts for May 1989 for Sequoyah Units 1 & 2
ML20244E318
Person / Time
Site: Sequoyah  
Issue date: 05/31/1989
From: Shell R, Shawn Smith
TENNESSEE VALLEY AUTHORITY
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
NUDOCS 8906200268
Download: ML20244E318 (58)
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SEQUOYAH 'HUCLvi2 PLANT (f,QN) - MAY 1589 MONTHLY OPERATING ~ REPORT U

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Euc)us,ed is tha May 1989 honthly Operating Report as' required by SQM Technical.

E Specification G.9.1,10.

If: you have ct y questiens conecming this tnatter, please ' call B. S. Schofield-.

si.-(615! H 3-6172.

Very truly youes,

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. U.S,. Nuclear. Repdatory. Commission Office of. Inspection and Enforcement Region II-

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' Rockvillef Ma@!.und :!tD852 le Mr. Ted Marston, Director Electric 3'ower Research Institute P.O. Box 10412 Palo Alto, California 94304 l-n Mr. B. A. Wilson, Assistant. Directo~

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' TENNESSEE VALLEY AUTHORITY 3m NUCLEAR POWER GROUP SEQUOYAH NUCLEAR PLANT 3

MONTHLY. OPERATING REPORT TO THE NUCLEAR REGULATORY COMMISSION MAY 1989

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UNIT 1 DOCKET NUMBER 50-327 LICENSE NUMBER DPR-77 UNIT 2 DOCKET NUMBER 50-328 LICENSE NUMBER DPR-79 Submitted by:

S. J. Smith, Plant Manager i

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TABLE OF CONTENTS Page I.

Operational Stsinary Performance Summary 1

Significant Operational Events 2-7 Fuel Performance 8

Spent Fuel Storage Capabilities 8

PORVs and Safety Valves Summary 8

Special Reports 8

Licensee Events 9-15 Radwaste Summary 16 Offsite Dose calculation Manual Changes 16 II. Operating Statistics A.

NRC Reports U

Unit 1 Statistics 17-19 Unit 2 Statistics 20-22 B.

TVA Reports Nuclear Plant Operating Statistics 23 Unit 1 Outage and Availability 24 Unit 2 Outage and Availability 25 Unit 1 Reactor Histogram / Analysis 26-27 Unit 2 Reactor Histogrem/ Analysis 28-29 III. Maintenance Summary Maintenance 30-35 Modifications 36-39 IV. Glossary Common Abbreviations and Systems of Sequoyah Nuclear Plant 40-43 Operational Modes 44 l

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OPERATIONAL

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PERFORMANCE

SUMMARY

. Mar 1989 ~

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The following summary describes the significar.t operational activities for the i

month'of May.

In support of this summary, a chronological log'of significant I

events is included in this report.

e Unit 1 Unit l' continued to operate well during May. 'It generated 843,500 MWh of l

electrical power with a cep; city. factor of 95.85 percent. 10n May 24, 1989, l'

'at-2356 (EDT),, the unit reached 100 days of continuous operation.

This is a standard milestone for TVA generating units greater than 500 MU.e Unit 2 On May 13, 1989, at 1340 (EDT), Unit 2 achieved 100 percent power.

This was a major milestone after Unit 2 cycle 3 refueling outage.

The. unit was online the entire month, gene' rating 763,500 MWh of electrical power, comprising a capacity factor of 86.75 percent.

The unit continued to have feedwater control problems. An action plan was' developed and approved, with concurrence from Westinghouse, to' determine how to initiate a transient into the feedwater control system and to identify what-parameters needed to be monitored during.the induced transient.

Results of' this induced transient showed the main feed pump was too responsive and the feedwater regulator valves were not responsive enough for full-pewer operation.

Consequently, the master controller for the main feed puinp turbines A and B speed controllers reset time constant was increased from 30 saconds to 120 seconds for each repeat.

In addition,'the feedwater regulator valve reset time constant was decreased from approximately 5 minutes to 2 minutes for each repeat.

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SIGNIFICANT OPERATIONAL EVENTS l

4 Unit 1 1'

Date Time:(EDT)

Event 05/01/89-0001 Reactor power at 100 percent, 1.175 MW.

e 05/29/89 2345 Started load decrease for maintenance on HDTP 3 motors 3A and 3C, and MFPs.

l 05/30/89 0505 Reactor poser at 76 percent, power reduction continues.

2116 Reactor power at 52 percent, 580 MN. Maintenance e

begins on HDTP 3 motors 3A and 30, and MFPs.

05/31/89 0128 Maintenance complete on MFP 1A.. Placing pump in service and increasing power.

1400.

Reactor at 58 percent. 660 MW, holding' status.

e 1518 Began removing MFP 1B f rom service f or various maintenance activities.

2119 MFP 1B returned to service.

2325 HDTP 3 recirculation valves 105A~and 105B are

repaired, Holding poder level.for. maintenance on HDTP 3 LCVs.. Reactor at 58 percent. 650 MW,

e 2400 Reactor power at 58 percent, 650 MW. Maintenance e

continues on HDTP 3 motors 3A and 3C.

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.SIGNIFICANT OPERATIONAL. EVE""j-

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Date Time (EDT)

Event 05/01/89 0000 Reactor power at 36 percent, 345 W. Aligning 1

e secondary equipment for sersice.

0645 Began load increase.

0704 Terminate power increase for tr S leakage verification.

1256 Began power increase.

2115 Reactor power at 44 percent, 433 W. Load increase e

terminated. Maintenance on HDTP 3.

Level controller does not respond to level change.

2233 RPI M-2 was found out of sequence with the other RPIs

- investigating.

05/02/89 0035

. Maintenance complete on RPI M-2.

0900 Began load, increase.

1353 Reactor power at 50 percent, 557 W. MFP A failed e

to load automatically, holding status until maintenance is performed. Pumps are to be specially field-tuned.

2118 Began power increase. Maintenance completee 05/03/89 1056 Reactor power at 75 percent, 793 W, hold for e

start-up testing.

1643 Thermal power verification performance, adjusted reactor to 73 percent.

05/05/89 1429 Started 1 cad increase.

l 1732 Stopped power increase because of intermediate range monitor being inoperable, 80 percent reactor power o 890 W.

e 05/06/89 0145 Holding for start-up testing. Reactor at 77 percent, 899 W.

e 1515 Decrease reactor power to 75 percent, 890 MW,

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'SIGNIFICANT OPERATIONAL EVENTS : '

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Date Time (EDT)

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05/06/89 1600

' Reactor power at-75 percent, 892'MW.

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. Intermediate range monitor operable af ter various SI/IMI performances.

05/07/89 1137.

Started power increase, m

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f 1718 Holding at 90 percent for reactor power verification,

.1,053 MW.

e 1738 Began lo6d increase.

1831

' Terminate power increase. Power icvel at 90 percent.

Temper &ture setpcint is. lower than required op-main

~ bank transformer.

.1854 Set point adjusted. Resume power increase.

u 2010 LOV-6-106B was found closed and would'not' reset.

Begin powe'r reduction to allow troubleshooting.

2307 Load decrease terminated at 80 percent, 960 MWet 05/03/89 0240 Placed LCV-6-1063 on HDTP 3 in service. Maintenance-complete on LCV.

1142 Started power increase.

1358 Stopped reactor power increase at S4 percent, 982 MW.

Holding for maintenance on ptessure q

e differential switch on HDTP 3.

1446 Main feed pump B swinging, impulse pressure swings.

l FW press are instrumentation failed. Power supply nee?s replacing. Various MCR alarms actuated.

1522 Experienced S/G 1evel swings,. along with governor valve swing.

1612 Reactor power at 84 percent, 982 MW.

o 2204 Decreane load, Maintenance on HDT? 3, lOV-6-1063.

Valve was again found closed. s

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105/09/69 0140

Power supply to the FW pressure instrumentation has b'eer. replaced, conitoring MCR indicator to ensure b

problem has been corrected.

0400 MCR instrer.cntatian no longer fluctuating.

.0500-Holding for spiking on extraction: pressure surge I '.

indications.

Began troubleshooting.

0730 Reactor power at 81 percent.

g, 1350 Maintenance complete on.HDTP 3 PDIS aad LCV-6-106B.

05/10/39 1703 3egin power increase.

1915 Reactor power at 90 percent; reantor power verification.

1945 Resume power incrasse.

05/11/89 0530

. Reactor poker at 99 perdent, 1,154 MW, Power e

increase stopped because of possible quadrant pcwer tilt retic analysis.

05/13/89 1239 hesume. power increase te 100 percent.

1340 Terminate power increase 1,171 MW.

e 05/14/89.

1745 Placed turbine control to MANUAL operation because of governor valve swing.

1826 Governor valves still swinging. Placing MFPs in MANUAL to stabilize swinging.

1955 Iccreasing ieactor t.o full. load.

05/15139 1004 neactor power at 99.5 percent,.1,172 Mu.

e 05/1G/89 1920 Increasing thermal power.

05/16/89 2400 Reducing load f rom 100 percent to 99 percent 3ecause of MFP swings.

05/17/89 0105 Reactor power at 99 percent. 1,171 MW.

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0455 Plac3d MTP in MANUAL because of thermal power nyings.

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0602 MFP master controller in AUTO, bn;t swing stabilized.

0727 Reactor power at 99 percent, 1,170 MW.

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SIGNIFICANT OPERA:! EAL EVNNTS

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05/18/87 1412

' Attempted t6 load "FP A up in MANL'AL. MFP.A would not respaud in MAWAL. Used the MFP caster controller to load MFP B up.

.1428 Started N load de. crease because of problems with-the MFF cottro11crs.

o 1927-St.arted unit: 2. cad reduction.

2150 Stopped power du.re,we, 98 percent, 1,168 W,

e 05/26/89-

'221L Resu%ed' lead reduction.

05/27/89 1049 hemoved MFP 2A irem service for outage, j

1451 Bes;an load increase to prcvide load for MFP 28.

1510 Terminated Icad increase to roadjust MFP contralier.

Reactor at 60 percent, 740 MW.

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.05/2S/69 0020 4egan performing adjsstinent meaeures on the main

. #eedwater regulator vaivas.

, f'I 0130 All adjust.ments have been made.

GA3 Placed MFP A in service for teia1 run to ob;ierve

' performance.

Pump is performing well.

0930 started load increase.

1247 Terminated power increase at M percent reactor power, 906 MW. Maintenanc6. required on CBP 2A.

e Investigate vibration and pump noise.

-1655 Started CBP LA.

'170T Maintenance completo on CSP 2A.

1904 Fogan powcr increase to 90 percent.

' b 2200 Reactor at-90 percent, 1,040 MW. Holding for p

e theruzl power verification.

2221 Test complete, begin power increase.

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Time (EUT)

Event (i

05/29/89 0249 Special thermal performance verification. Reactor at 99 percest, 1,166 W.

e 0345 Place $ 2 percent load decrease at 2 percent per minute, 96 percent to 94 percent for this special test on MFW.

0347 Started load swings for special test on MEW regulator-valves and MFP ta determine affect of valve twings.

0427 Began load increase. Test was successful; valve 6 wings were minimal.

0600 Reactor power at 100 percent,1,172 MW.

e 05/31/89 2400 Reactor at 100 percer.t. 1,172 MW.

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FUEL PERFORMANCE e

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-The core average, fuel exposure accumulated during May was 1,150 mwd /MTU, with a total accumulated core average fuel exposure of 3,794 mwd /MTU.

. Unit 2 The ; ore average fuel exposure accumulated during May was -1,031 :Ed/MTU, with

a. total accumulated core average fuel exposure of 1,076 mwd /MTU.

SPENT FUEL PIT STORAGE CAPA3ILITIES

,e The total storage capability in the SFP is 1,386 bundles. However, there are E

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 unaval.'.able because of an instrumentation conflict.

Presently, there is a tetal of 428 spent-fuel bundles stored In the

.SFP.

The remaining storage capacity is 952 bundles.

PORVs AND SAFETY VALVES SDNARY

.No PORVs or safety valves were challenged in May.

SPECIAL REPORTS There were no special reports for the month of May.

LERs The following pages are copies of cover sheets of LERs that were reported to the Nuclear Regulatory Commission in May 1989.

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On April 16, 1989, at 0040 EDT, unit 2 entered mode 1 with Rod Position Indicator (RP1) 15-12 inoperable. RPI H-12 had been teclared inoperabic and 3.1.3.2 entered at 2240 EDT on April 15, 1989. The action statement for Limiting Condition for Operation (LCO) 3.1.3.2 requires no action if reactor power is below 50 percent.

inoperability of the RPI channel tras discussed among the on shif t personnel The prior to the mode change and it was decided that since no action was required below 50 icreent powne, they agreed that it would be acceptable to proceed to mode 1.

llowever. LCO 3.0.4 statea that entry into an operational node shall not be made with rollanco on the provisions contained in the action requirements, and LCD 3.1.3.2 doon not contain an ekception to LCO 3.0.4 During troubleshooting of Rpl charinol 1(-12 on April 17., 1989, it was discover ed that the connector at the Kvertleal panel on the rec tor head had failed due to moisture deterioration. Thr2 connector was replaced and tir.e.hannel returned to service at 0630 EDT on April 17. 1989. The personnel ina!ved in the trode change decision failed tra fully cunnidor tho offects of LCO 3.0.4 As a corrective moamre, TVA will issue a

. training letter by tiay 23, 1989, on thic event to be reviewed by operations personnel to prevent future reoccurrence.

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,...., u c.,,,..~,.,,, ii D This report details three unit 2 reactor trips which occurred on April 15, 1G, and 19, 1989 following the completion of the unit 2 cycle 3 refueling cutage. For all three events operator actions (performed in accordance with plant procedures)

I caused steam generator (SG) water levels to begin fluctuating and, subsequently, a i

reactor trip due to low-low water IcVel in one of the SGs.

For the April 15 event.,

unit 2 was at 30-percent reactor power and in the process of performing a main turbine overspeed test when the reactor tripped due to low-low water level in SG No. 4.

For.the April 16 event, Operations was in the process of performing a swapover from auxiliary feedwater (AFW) to main feedwate:- (MFW) supply to the SGs l

when the reactor tripped due to 1ow-low water level in SG No., 1.

For the /tpril 19

c. rent, during normal power escalation (18-percent reactor power), Operations was in the proctecs of swapping over frem the MFW bypass valves to the MFW main regulating l

valves when the reactor tripped due to low-low water level in SG No. 2.

The April 15 c%se was allowing SG 1evel conditions to degrada (wide swings) to where

. recovery was extremely difficult, before terminating nonessential activities, l

discussing alternative nethods of level control, and regaininr, control of plant I

conditionc. The April 16 cause was an out-of-calibration condition on 2-pT-3-1 (MFW pump discharge pressure). The cause for the April 19 trip was operating loops 1 and 2 bypass valves in manual and not allowing sufficient time for the system to stabilize after each transient. liumerous corrective actions are planned to be taken as detailed in TVA's letter to the URG dated May 3,1989.

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On May 5.1989, at 0600 EDT, with both units in mode 1. unit 2 entered Technical Specification (TS) Limit.ing Condit

  • on for Operation (LCO) 2.2.1 af ter it was determin d l

that, unit 2 had. operated in noncompliance with the LCO since April e

l' discovered that the reactor trip setpoints for both Nuclear Instrumentation System (N 11, 1989 It was intermediate range (IR) channels were greater than the TS allowed 30-percent power valuo.

Prior to this event, unit 2 had been in a refueling outage during which time thers was a near continuous probicm with excessive noise on both source range (SR) de t ec t. ors.

to climinato the excessivo noise.With West.inghouse assistance, various actions had been One such action taken was the removal of a ground strap to eliminate ground loop rdurrents in the SR detector cabling at the SR/IE dcte: tor hou s int,.

Another action taken at this same t.ime was to move the SR/IR detector cart from the fully inserted position to the fully withdrawn position to eliminate detector hardline cobic abrasion on the cavity wall.

turther f ron the core, a higher reactor power icvel was required for a given IRWith the IR de E

current.

set. point was greater than the TS allowed value.,The effeet was not compensate The IE c.hannel bistables were Kay 1. 1989. at 0353 EDT.recallbrated to the required setpoints, and tha channels were re relocation and remained operabic' t.hroughout the event.It *<ag determined that the ER As a corr 0ctive ceasure to prevent and documentation of the position of the tilS detcetors and verificatio performance.

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At 0930 EDT. on April 13, 1989, with unit 1 in mode 1 (100-percent power, 2235 psig and 578 degrees F) and unit. 2 in modo 2 (less than one-percent, power. 2235 psig, L

and $47 degrcos F), tho shift, operations supervisor (503) was notified of a deficiency in the residual heat removal (RHR) pump test, procedures S1-128.2 and

-128.3, which close the RHR cross-tle valves (74-33, 74-35) and the cold icg injection valves (63-93, 63-94) at various times during the performance of these proceduros. Clonuro of any one of these four valves rendors the RHR system lneapablo of delivering flow to all four loops as assumed to the accident analysis, p1deint, unit 1 in Technical Specification (TS) Limiting Condit.lon fot' Operation (LCO) 3.0.3.

Two performances were dos.umented as having been performed while unit I was in node 1 (S7-128.2 on February 24, 1984 and SI-128.3 on March 1, 1989). At 1006 EDT, the NRC was notified that. the two previous performances had pinced the plant in a condition outside the design basis assumed in the accident analysis. On Aprl1 20 1989, the Hechanical Test. supervicor centacted the SOS to prohibit perf ormanco of SI-128 socios until t. hey could be revised. It was determined at this time that 51-128.1 had been performed between 0200 EDT and 0635 EDT carlier that day.

The Mechanical Test supervisor informed the SOS that LCO 3.0.3 chould have boon entered. At 1257 EDT. the NitC was notified that during the performance of 51-128.1 between 0200 EDT and 0635 EDT, the plant had been placed in an unans tyred condition due to the hot. leg itsjection path being open while the ECCS was.iligued for cold leg inj ec t,lon.

The immediate cause of the first event. was an inadequeto proceduro revision in December 1988 that changed the valve lincup used during pump testing. However, the root couso of this incident continues t.o be investir,ated. The appropriate plant procedures, as well as the SI-128 scrics, are being revised to properly address those unacceptable plant. configurations.

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,,, o s, At 9 approximately 0505 EDT. on April 10, 1989, with unit 1 in mode 1 (100-percent power, 2235 psis, and-578 degrees F), a containment ventilation isolation (CVI) occurred on unit 1.

An apparent spurious high radiation spike occurred on the nobic gas channel of lower containment radiation innitor (RM) 1-RM-90-106 which cauced the CVI.

The assistant shift operations supervisor (ASOS) responded to the CVI signal and noted a high radiation spike on noble gas channel of 1-RM-90-106.

Further review of the RM reccrder cha"t indicated that, only the noble gas channt-1 had spiked, and the spike was instantancaus without any decay tine, and it was concluded that. the high radiation spike was spurious. Subsequently, the ASOS s

verified that upon receipt of the CVI signal all equipment functionce' as designed, and inst meted t he unit operator (UO) to initiate recovery from the CVI, The cause i'

of the spotious high radiation spike is unknown at the present titue. An immediate

  • corrective action, unit i Cperations personnel verified that the CVI was not a result of an actual high ra:iistion condition in the unit I containment and l

initiated recovery f rom the CVI in accorf.ance with System Opet-ating Instruction (001) 30.7B, " Containment Itrge System Ope"Mion." At approximately 0533 EDT. on 4

f.pril 10 19B9, both upper and lower containment RM were returned to service.

TVA 19 continuint to investigate the cauce of the spurious high radiation spike which occurred on the RM and eilll revise this L.ER to update llRC on the results of the invcutigation.

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On May 3, 1989, with unit 1 in mode 1 (100-percent power, 2235 psig, 578 degrecs F),

l and unit 2 in mode 1 (54-perecnt power, 2235 psig, 563 degrecs F), a train "B" control room isolation (CRI) occurred. At approximately. 0051 EDT, a train "B" CRI signal, as indicated on panci 0-M-27, was roccived in the main control room (MCR).

Subsequent to receipt of t.he CRI signal, the assistant unit operator (AUO) who was perfotning chart paper replacement on t.hc recordce for radiation monitor (RM) 0-RM-90-126 informed the assistant shift operations supervisor (ASOS) that he had inadvertently bumped the RM pump motor breaker.

The MCR intake RMs 0-RM-90-125 (train "A") and 0-EM-90-126 (train "B") monitor the discharge flow of Control Building (C3) norraal prescuritation fans that take suct. ion from outside air and provido ventilt. tion to various CD atece riuring normal plant operation.

During the veplacaent of the chart paper, the ADO lost control of the chart paper take-up rect assembly in the procosu of placing the assembly en top of the RM cnclosure.

As a reflexive acticn, his knee came up to tt*y to catch the assembly.

As a result of this motion, the ADO bumped the cumple pump motor becaker.

Tho KHs are blocked E

before performance of maintenr.nce work or tests, but this is currently not censidered to bc a requirement for changing the chart paper. As immediate co"rective f.ction, operations peruonnel verified that the CRI was not a result of an actual hit,h radiation condition and initiated recovery from the CRI in

,accordance with System operating Instruction (S01)-30.1B " Control Building and Cont. col Roem ilenting, Air Conditioning and Ventilation System."

At approximately 0114 EDT. the CD ventilation system was returned to normal operation configurat. ion.

This cuent, will be discussed in nonlicensed requalification work activitics when working around these and similar monitors. training t I^

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  • 4 escatify haut su DDralT huwst#1 ip Seouovah, Unit 1 e 4.e. 3, o 15 I o t o ; o 131217 1 lo4016 Control Power fuse Opened During Replacement Of Indicating Lamp k'hich Caused A DG To Become Inoperable And Resulted In Enterine LCO 3.0.5 For Both Trains Of ABCTS Inoperable svs=vcave m i

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y On May 6,1989, at 1000 EDT, with unit.1 in mode 1 at 100 peretnt reactor power and unit 2 at, 75 percent reactor power, Limiting condition for Operation (LCO) 3.0.5 was entered af ter both trains of the Auxiliary Building gas treatment system (ABGTS) became technically inoperabic. Before the event, "A" train ABGTS had been removed from service on May 5, 1989, to perform routine preventative maintenance. On May 6,1989, an assistant unit operator (AUO) discovered that the red lamp which indicated, " Control Power On," at the local control panel for 6.9kV cmcrsency diesel generator (DG) 2B-B was not illuminated.

During the process of replacing the indicating lamp, a control power fuse opened.

DG 2B-B is the emergency power source for the "B" train of ABGT3.

The opened fuse caused DC 2B-B to be it:operabic and hence, entry into LCO 3.0.5 was required i

because both trains of the ABGTS were techni.cally i'ioperabic.

The root c ut.c of this event is attributed to the AUO wiggling the bulb in the lampholder, thereby creat inn, 3 short encuit, causing the controi power fuse to open.

A contributing cruce of this

. event. was the lampholder which al?. owed encugh bulb movement during the wiggling to cause

'a short circuit.

Operations im:tedintcly rerponded to a centrol power f.allt.re aLnm

' determined which fuse had blown, and replaced the fuse. The corrective action to be taken to preclude recurrence vill include revising Isdminir:trative %nsttveti:n ( AI) 30,

" Conduct of Operation " to empha;ize to operators to exercise caution when replacing indicating lamps.

Additionally, a training 1ctt.cr will be issued to liecnsed operators, AU0s, and r,hifL technical advisors (STAS) to ut resa the consequences of not exercising caution during replacement of indicating lamps and the need to initiate a work request i

(k'R). to repair any equipment that does not operato, rather than attempting to force equipment to operate.

Other currectiv? action already co:rpleted is the replacement of the lampholder that allowed the bulb to be inserted in a manner to cause a short circuit.

Also, a permanent caution tag will be placed on the DG local control panels to warn operators of the potential impact of replacing indicating laeps and to instruct-them t o tace caution.

n.c,e.....

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n" RADWASTE SD: MARY-May 1989 1.- Total volume of solid waste shipped offsite:

A.

Dry active vaste:

0 Activity:

.N/A curies B.-

Spent resins, sludges, bottoms:

475.5 ft3 Activity:

6.6835 curies Shipped: Barnwell, Inc. - May 4, 1989 (2)

May 9, 1989 (2)

May 15,'19S9 (2) 2.

Radwaste onsite and awaiting shipment:

A.

Resin in' storage:

142.0 ft3 B.

Estimated resin that will be generated:

39.0 ft3 C.

Dry active waste awaiting shipment:

1353.0 ft3-1 - Dry active vaste 2 - Spent resin 3

0FFSITE DOSE CALCULATION MANUAL CHANGES No changes were made to the Offsite Dose Calculation Manual for the month of May.

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DOCKET NO. 50-327

'DATE JUNE 06, 1989 COMPLETED BY D.C.

DUPREE TELEPHONE (615) 843-6722-OPERATING STATUS 1.

UNIT NAME: SEGUDYAH NUCLEAR PLANT, UNIT 1

NOTES:

2.

REPORT PERIOD: MAY 1989 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 8.

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 3623.00 69408.00
12. NUMBER OF HOURS REACTOR WAS CRITICAL 744.00 3574.25 28398.69 13, REACTOR RESERVE SHUTDOWN HOURS 0.00 0.00 0.00
14. HOURS GENERATOR ON-LINE 744.00 3548.66 27612.54
15. UNIT RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

'16.

GROSS THERMAL ENERGY GENERATED (MWH) 2459688.72 11873166.93 89450103.80

17. GROSS ELECTRICAL ENERGY GEN. (MWH) 843600.00 4091470.00 30226746.00
18. NET ELECTRICAL ENERGY GENERATED (MWH) 814873.00 3950364.00 28871792.00
19. UNIT SERVICE FACTOR 100.00 97.95 39.78
20. UNIT AVAILABILITY FACTOR 100.00 77.95 39.78
21. UNIT CAPACITY FACTOR (USING MDC NET) 95.41 94.98 36.23
22. UNIT CAPACITY FACTOR (USING DER NET) 95.41 94.98 36.23
23. UNIT FORCED OUTAGE RATE O.00 2.05 54.26
24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH):

AN ICE OUTAGE IS SCHEDULED IN OCTOBER 1989, WITH A DURATION OF 12 DAYS.

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

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

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TELEPHONE :.(615)843-6722 MONTH: MAY~1989 AVERAGE DAILY. POWER LEVEL AVERAGE DAILY POWER LEVEL DAY (MWe' Net)

DAY (MWe Net) 01-1127 17 1132

~02' 1124 18 1130 03

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1130 26 1125 411 1128 27 1124 2

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DOCKET NO. 50-329 DATE JUNE-06, 1989 COMPLETED BY D.C.

DUPREE TELEPHONE (615).843-6722 OPERATING STATUS

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UNIT NAME: SEGUDYAH NUCLEAR PLANT, UNIT' 2 NOTES:

2.

REPORT PERIOD: MAY 1989

^

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

~ 0.

IF CHANGES OCCUR IN CAPACITY RATINGS (ITEMS NUMBERS l

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 3623.00 61368.00
12. NUMBER OF HOURS REACTOR WAS CRITICAL 744.00 1395.72 28582.36
13. REACTOR RESERVE SHUTDOWN HOURS 0.00 0.00

~ O. 00 14 HOURS GENERATOR ON-LINE 744.00 1260.97 27852.94

15., UNIT RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

-16.

GROSS THERMAL ENERGY GENERATED (MWH) 2208995.94 3321583.61 850456814 67

17. GROSS ELECTRICAL ENERGY GEN. (MWH) 763500.00 1123380.00 28812100.00
18. NET ELECTRICAL ENERGY GENERATED (MWH) 735099.00 1019200.00 27440296.00
19. UNIT SERVICE FACTOR 100.00 34.80 45.39
20. UNIT AVAILABILITY FACTOR 100.00 34.80 45.39
21. UNIT CAPACITY FACTOR (USING MDC NET) 86.07 25.23 38.95
22. UNIT CAPACITY FACTOR (USING DER NET) 86.07 25.23 38.95
23. UNIT FORCED OUTAGE RATE O.00 19.44 48.81'
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:

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

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SEQUOYAH NUCLEAR PLANT j

AVERAGE DAILY POWER LEVEL DOCKET NO. : 50-328 UNIT : TWO DATE : JUNE 05,1989 COMPLETED BY : D.C.DUPREE TELEPHONE-: (615)843-6722 MONTH: HAY 1989 AVERAGE DAILY POWER LEVEL AVERAGE DAILY POWER LEVEL DAY (MWe Net)

DAY, (MWe Net) 01 346 17 1132 02 454 18 1128 03 731 19 1120 04 798 20 1124 05 860 21 1116 06 898 22 1116 07 898 23 1116 08 928 24 1114 09 928 25 1110 10 950 26 1106 11 1110 27 793 12 1119 28 801 13 1130 29 1128 14 1131 30 1132 15 1131 31 1134 16 1132.

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NUCLEAR PLANT OPERATING STATISTICS Sequoyah Nuclear Plant I

j peri 6d Hours 744 Month May 19 89

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ttem No.

Unit No.

UNIT ONE UNIT TWO PLANT l

1 Averace riouriv Gross Load, kW 1,133,871 1,026,210 1,080,040 2

Maisimum Hour Net Generation, MWh 1,140 1,140 2,276 3

Core Thermal Eneroy Gen. GWD (t)2 102.4870 92.0415 194.5285 7

i 4-Steam Gen Thermal Eneigy Gen.. GWD (t)2 102.8894 92.4662 195.3556 5

5 Gross Electrical Gen., MWh 843,600 763,500 1,607,100 5

6 station use. MWh 28,727 28,401 57,128 h

7 Net Electrical Gen.. MWh 814,873 735,099 1,549,972' 8

Station Use. Percent 3.41 3.72 3.55 9

Accum. Core Avg. E xposure. MWD / Ton!

5,794 1,076 6,870 10 CTEG This Month.10 BTU 8,394,918 7,539,303 15,934,221 6

11 SGTEG This Month.106 BTU 8,427,877 7,574,091 16,001.969 12 13 Hours Reactor Was Critical 744.0 744.0 1,488.0 14 Unit Use. Hours Min 744:00 744:00 1,488:00 15 Caoacity Factor, Percent 95.85 86.75 91.30 R

16 Turbine Avad. Factor Perf ent 100.0 100.0 100.0 17 Generator Avan. Factor. Percent 100.0 100.0 100.0_

C 18 Turboe,an Avail Factor. Percent 100.0 100.0 100.0

$ _ 19 neactoi Ava.t. Factor. Percent 100.0 100.0 100.0

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20 Umt Avaa. ractor. Percent 100.0 100.0 100.0

_21 Turbine Startuos 0

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22 Reartoi Cold Startur's 0

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24 Gross Heat Rate. Bru.kWn 9,950 9,870 9,910 E

?5 Net Hest Rate, Rtu/kWh 10,300 10,250 10,280

.5 26 Gross P. eat Rate Btu /kWh (w/ oil) 9,910 C

?7 Net Heat Rate Btu /kWh (w/ oil) 10,280 g

28 Tniottie Picssuie. ps g 851.8 855.9 853.8 29 Tnrottie Temperature. ' F 525.5 526.0 525.8 y

'30 Exhaust Peessure. InHg Abs.

2.06 2,07 2.07 E

31 intake Water Temo..

  • F 64.7 67.5 66.1 5

32 33 Main Feedwater. M inint 14.3 12'.9 13.6 E

34 35 36 37 ruit Powei Cautaity. E FPD 404.86 411.6 816.46 38 Accum. Cycle Full Power Days EFPD 151.3380 28.1857 179.52 N

39 Od F red for Generation. Gahons 2,046 138,000 2

40 Od Heatino Valoc. Htu/ Gal.

31 41 Diesef Generation. MWn V

Man. Hour Net Gen.

Max. Day Net Gen.

Load I

MWh Time D a't'e MWh Date F actor. %

3 43 2.276 2.300 5-16-89! 54,280 5-15-89 91.53 R emai k s < 4 For BF NP ttus value is MWD /STU and for SONP and WBNP this value is MWD /MTU.

j 2(t) endicates Thermal Energy.

7 cf Date Sutsmitted Date Revised 8

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UNIT-1 REACTOR HISTOGRAM ANALYSIS' 4

Unit i 1.

Reduce load'(holding for), maintenance on HDTP, motors 3A and 30.

. Maintenance on A and B MFPs.

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UNIT 2 RF. ACTOR HISTOGRAM ANALYSIS l

Up.it 2 1.

Putting' secondary systems in service.

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Maintenance on HDTP 3, level ec-troller.

3.

Maintenance on the MFPs.

4.

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5.

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6.

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I 7.

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8.

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9.

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10.

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106/12/38,;.

2-2WO634118-A, y ;"fn4/08/88.

During Unit 2 outage, an incidental observation indicated that SIS accumulator tank 1 ficw isolation valve was leaking boron. Failvre g

A-was attrib.Ited to loose packing. Boron was cleaned from the valve

. and piping, valve packing was adjusted ard the valve was returned to service. (WR B780606).

10/12/88,.

" 1SG-0624073-A, 10/13/88 '

Mtila Unit 1 was in ncn-nuclear heatup, an audiovisual slam indicated regenerative heat exchaiger Intdown irolation v&lve B sras,

closirg without Mdswiteit operation. The solenoid call was defective W uco cf water in the solenoid houeing, possibly caused frm a decontamination spraydown arourd the seal' table aM raceway.

Replaced soloncid valve aM recrannected tubing. Verifled resistance readings, verified coil voltage ratirg was 1P5-V de ard returned valve to service. (WR B237128).

.01/28/89, 2-MVOP-062-0133-B, 03/15/89 During Unit 2 refuelirg cutage, a special inspection of the volume i

control tank outlet level control'and isolation valva operator iMicated poor grease quality in the main gear box. Failure was attributed to breakdown in lubricating capability !xcause of a mixture of greases of different chonical bases. The cc.pt performed its designed furction, but wuuld have been degraded h6d it not have been repaired. Disassembled and rebuilt operatcr.

Reassembled operator, replaced lubricant aM returred to service.

p.

(WR B261016).

02/11/39.,

2-MVOP-067-0491D-A, 03/26/89L During Unit 2 Iefueling outage, a surveillance test indicated that ERCW header A strainer fluthout va3va would not operate electrically or mechanically. A bad. rotor capacitor was disccucred, along with dirty atacts and oil in the 21mitswitch compartmnt cover. Also fourd breakdown in lubricant bmwm of rust and water in the gear box. Replaced a lo-amp control fuse in compartment SC 2A-A motor control center, totor capacitor and operator oil. Functionally tested valve and returned to service. (WR B280974).

. 1

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19 Electrical 14anthly Report:

04/01/89, 2-INVB-250-QU-G,

'C4/03/89 During Unit '2 refueling cutage, an incidental. observation indicated

~

120-V ac vital inverter 2-IV capacitor bank *as emitting a burning.

saell. Total failum of the camponent occurred before corrective action oculd be initiated. Capacitors C1 and C406 blew up b3eause of age. Prevuttive maintenance had not bee'1 parformed, resulting in the capaciters nWirg their t m - 'ided life. Replaced capaciter banks C1 and C406. Replaced oscillator, shorting diode and

synchronizing boards and also replaced four resisters and four diories.as preventive maintenance measures. Replaced ESl fen notor because of a bad switch. Energized inverter and did not get synchronization light because of an accidental switching of the 120-V ac relt eith the 12-V de relay. Replaced fuses and RL1 relay and returrnd to service. (WR R28J063).

' G4/09/69, P COIA-250-RQ, 04/11/tl9 Durirg Unit 1 operatien, a visual alarm indicated 120-V ac fMferred inverter 1 failed. F101 ard F103 fuses blew temm of a defective circuit. Replaced F101 arri F103 fuses and adjusted oscillator card. Set sign waite and synchronize 3 both invuter and voltage. Set appdrent voltage to true voltage (12?.0. &c} without load and r@2rned to cerviw. (WR B256266).

05/02/89, 2-MV0p-003-0175-A, 05/03/89 Durintj Unit 2 cperation, a visual alarm indicated S/G 4 ICI indicator lights were showing Mth.open and closed valve positions.

The actuator ar;a on the vahe stem was out of. adjustment. This is a

(

generic Masoneilan stem rotation problem. Adjusted actuator an2 and.

returned valve to service. (WR B790969).

05/04/89, 1-ICIC-003-0003,

05/05/89 During Unit 1 operation, an audiovisual alc,pn indicated 4f>0-V turbine building motor-cperated valva board 1A control transformer, in compartment.11B, was burned up. Fuses were over-rated for the L

transformer. Replaced the control transformer arxl returned to service. (WR B790934).

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Instrument Monthly Report 09/02/88, 2-M70P-003-0156-A 09/04/88 Durirg unit operation, the main and auxiliary fecchrater S/G 2 ILV stem appeared to be birdirg and would not pass stroke time test in accordance with SI-166, "Summry of Valve Tests for ASME Section XI,

- Units 0, 1 and 2."

Troubleshooting of valve revealed a defective quick exhaust valve. 'Ihis may have been because of the age cf the equipment ard/or cycliry fatigue. Replaced relay "mmhly, gasket, roterirg tube ard exhaust valve. Ierformed postmaintenance test and verified proper operation of the valve. (WR B789278).

01/19/89, 2-FCV-087-0023-F, 04/02/89 During unit outage, the UHI system isolation FCV response time was fourd outside of allwable limits. Failure was attributed to a Ivptured bladder possibly caused from age of equipment and/or cyclirg fatigue. Raplaced ruptured bladder ard verified response time for valve. Returned to service. (SI-196, " Periodic Calibration of Upper Head Injection System Instnmentation (18 Honths), - Units 1 ard 2").

01/19/89, 2-LT-087-0001, 04/02/89 Durirg unit outage while performing SI-196, the UHI system mrge tank level traru= titter was fourd outside desirtd tolerance. Root cause is unknown. Cause may have been cyclirg fatigue. Recalibrates ard returned to sen' ice. Verified proper operation. (SI-196).

01/19/89, 2-LT-087-0004, 04/02/89 Durirg unit outage, the UHI system level irdicator surge tank level transmitter was fourd outside desired tolerance while performiry SI-196. Root cause is unknown. Cause may have been cycling fatigue.

Recalibrates and returned to service. Verified proper operation.

03/09/89, 2-SC-068-0339B, 03/29/89 Duri1g unit outage, system engineer requested that the RCS pressurizer charnirq pump speed controller be calibrated because of length of time since last calibration. Calibrated the controller and left in tolerance, Returned to service and performed postmaintenance testing. (WR B775277).

03/09/89, 2-SM-068-0339, 03/29/89 Durirg unit outage, system engineer requested that the PCS pressurizer charging ptrup speed modifier be calibrated bcause of leryth of time since last calibration. Replaced the relay assembly ard calibrated the modifier to desired tolerance. cause may have been the age of equipment ard/or cyclirg fatigue. Returned to service ard performed postmintenance test. (WR B775277).

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p Instrument Mon?hly Report n-

'~03/26/89, 2-LT-063-0109, 03/29/89

'During unit outage, the SIS level transmitter on accumulator 2 had greater than 5 percent deviation in reading than 2-LT-063-0099.

Failure was detected by incidental observation. Failure was attributed to shift in settings possibly from age of equipment and cycling fatigue. Recalibrates to desired tolerance ard returned to service. (WR D757231).

03/28/89,-

2 'IM-074-0038C, 03/29/89.

During unit outage, the RHR system' outlet heat exchanger A temperature modifier was found to be reading Icw and out of desired tolerance while performing SI-288, " Calibration of Cooling 7bwer Blowdown Flow and IcVel Instrumentation (550 Days), - Unit 0."

The as-found values were lower than the required operational specifications. Root cause is unknown. It may have been Waum of age and/or cycling fatigue. Recalibrates to desired tolerance and returned to service.

03/28/89, 2 'IM-074-0040C, 03/29/89 During unit outage, the RUR system outlet heat exchanger B temperature acdifier was found to be reading low and out of desired toleran while performing SI-288. The as-found values were lower than the required operation specifications. Root cause is unknown.

Cause may have been because of age and/or cycling fatigue.

Recalibrates to desired tolerance and returned to service.

'03/31/89,.

2-FT-063-0092B, 04/01/89 During unit outage, the SIS flow to RCS 1 & 4 cold log flow transmitter was suspected to be reading low and out of calibration.

71 tis failure was detected through incidental observation and was lower than the required compliance specification. Recalibrates to desired tolerance and returned to service. Potential reportable occurrence 2-89-059 was initiated and submitted for analysis. (WR B283067).

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MECHANICAL MAINTENANCE E

MONTHLY REPORT FOR MAY 1989 L

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Unit 1 1.

Completed maintenance on various valves, limit switches, and pumps on system 6.

2.

Completed repair on HDTP 3 pump Cuno filter.

3.

Completed inspection on D/G 1A-A.

i; 4.

Completed repair on stator cooling water pump.

5.

Installed new coupling and realigned boric acid concentration pump.

l Unit 2 1.

Completed repair on condensate booster pump 2A.

2.

Installed new AC oil pump on D/G 2A-A and 2B-B.

3.-

Installed new rupture disc on BAE B.

4 Completed inspection on D/G 2A-A and 2B-B.

5.

Repaired leak on S/G blowdown heat exchanger head.

6.

Completed repair on bus duct cocler fan 2A.

, Unit 0 1.

Performed various maintenance activities on NMUDT system.

2.

Completed repair on 0-VLV-14-300.

3.

Retubed BAE vent condenser A.

4.

Rebuilt air starter motors for all D/Gs.

5.

Completed repair on Su11 air air compressor.

6.

Rebuild glycol chillers D and G.

Other 1.

Continued closure of various CAQRs, CARS, etc.

Mechanical Monthly Report i

04/11/86,.

2-VLV-068-0541-S, 05/18/86 Durirg Unit 2 shutdcun, the RCS loop 4 hot log manifold isolation valve was discovered to have been leakiry at the bolted bonnet.

Failure was Watm of gasket age and theIral cyclirq. Cleaned boren off of the valve ard installed new bonnat gasket. (WR B105613).

03/16/89, 0-VLV-061-1021, 04/26/89 Durirg Unit 2 cycle 3 refueling outage, the ice condenser glycol circulation pump A casing drain valve was discovered leakdtg through while the pump was in service. Failure was attributed to wear on valve diaphragm. Cleaned and installed new valve diaphragm.

(WR B256653).

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MAINTENANCE SUW.ARY

-(MODIFICATIONS)

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SUMMARY

OF UORK COMPLETED MODIFICATIONS - CURRENT STATUS MAY 1989 1.

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Ms5or Capital Projects:

PN7108: ECN 6720 - Crane Consistency Program Unit 1 polar crane limit switch weights remain to be painted.

Completion is scheduled for Unit 1 cycle 4 (U1C4).

Completed cranes - Unit 1 Turbine Building 15-ton crane, Unit 2 polar crane, Unit 2 Turbine Building 200-ton crane, Unit 2 Turbine Building 15-ton crane, Service Building 5-ton crane, and Turbine Pullding 10-ton hatchway crane.

Remaining listed cranes are to be modified after Unit 2 cycle 3 (U2C3) - Auxiliary Building 125-ton crane, vaste packaging crane, railroad bay crane, and Unit 1 Turbine Building 200-ton crane.

PN7130: ECN 6190 - Postaccident Monitoring Work is currently being held for material.

PN7161: -ECN 5855 - Replacement of Doors A56 and A57 WP 09679 remains on hold and is partially complete.

Other Items:

ECN 5111 Provide Permanent Power to Manholes 42-46 Work has stopped because of lack of fundin;. The cable has been run from breaker 4E at the 480-V common board in the Turbine Building through manhole 1 to manhole 42.

All material was purchased before the job was stopped for lack of funding. Work is 45 to 50 percent complete.

ECN 1250 - Modification to New Fuel Deck Grating WP approved but revision required to reduce scope of work. This WP will close a plant TACF.

ECN 5503 - Evacuation Alarms OLPS/ Fire Detection OLPS WP 12482 - Work has stopped because of lack of funding.

ECN 5552 - Condensate Demineralized Modifications and High Crud Filter WP 5552 Fieldwork is complete.

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i Other Items (coa 2.):

ECN 5609 - Alteration to the Makeup Water Treatment Plant

.WP 12387 - Work is 90 percent complete. WP is available to work.

WP 12576 - WP closure is in process.

WP 12633 - Work is approximately 90 percent complete because of redesigns.

WP 12665 - Work i; is'1d complete. WP is in final closure.

WP 126E2 - WP is 80 percent complete. Awaiting installation of a pump for the alum sludge pond.

VP 12684 - WP is field complete.

Equipment calibration and functional tests remain.

WP 12731 - WP closure is in proces*,.

ECN 5841 - Hot Shop Fire Protection / Evacuation Alarm WP 12360 is field. complete. Awaiting drawings to be updated.

ECN 5855 - Modification to A56 Door'Haadwheel WP is in progress to complete required modification to close plant TACF.

ECN 5911 - Waste Disposal Piping Addition System tie-ins are complete. Work is in progress to fabricate a temporary spool piece to support performance of the PMT.

ECN 5916 - Replacement of Cask Decon Collector Tank Pumps Concrete poured for one pump foundation.

LCN 5935 - Correct Power Block Lighting Deficiencies WP 12437 is complete. WP 12275 is complete. WP 5935-01 is field complete. Waiting on secondary drawings to be revised.

WP 5935-02 is field complete.

ECN 5977 - Install Steam Generator Blowdown Demineralized System tie-ins are planned for refueling outage.

Other Items (cont.):

1 ECN 6357 - ERCW Roof Access and Rails for Security Equipment Original design for WP 12238 was rejected by Operations. NE to rework design to comply with Operations' needs and attempt to salvage existing work.

ECN 6388 - Hydrogen Monitors in Switchyard WP 12223 - Funding has been approved. A purchase request has been prepared to send the probes and monitors to the vendor for checkout and calibration.

ECN 6429 -~ Component Cooling Heat Exchanger Replacement Work on heat exchanger B is complete, except for insulation and painting. Work on heat exchanger C will resume as soon as funding is approved.

ECN 6815 - 500-kV Switchyard Addition A 30-liter air replenishing tank was purchased to replace a defective tank on PCB 5018. This tank wa received onsite May 2, 1989. Additional testing has revealed air leaks

.n tne replenishing valves. These are caused by a pitted surface on the valve pistons. An attempt will be made to remove the pits by polishing or machining the damaged surfaces.

Testing remains for the switchyard data acquisition. A decision has been ma!e to retire the 161-kV equipment in bay 20 by leaving it in place.

This decision will require revision ot' design drawings by means of an FCR.

FCP 8087 has been submitted to NE to revise the drawings. Awaiting FCR approval.

- DCN 214 - AFW Tap Rotation Work is complete, PMT required.

ECN 7328 - Installation of Backflush Line Spent Resin Storage Tank Drain Line WP is approved and pref a'orication of new piping and one support is in progress.

ECN 7349 - Removal of Temporary Bull Hose from CDWE to Floor Drain Collector Tank Tie-in of new piping is scheduled to begin June 1989 followed by removal of bull hose.

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Other' Items (cont.):

DCN 1042 - Nuclear Telecommunications System Project Work has started on the installation of the handholes and conduit bank.

The work has now progressed from Igou Ferry Road to the east end of the Design Services Complex.

DCN 1361 - Modification of Auxiliary Feedwater Pipe' Support to Resolve Plant TACF Completed required modification and closed TACF.

PCN 30

- Civil Call Pipe Support Project Wrote, _pproved, and issued to craft 14 WPs to begin the post-U2C3 nonoutage modifications of approximately 1,400 pipe supports. Craft to complete 21 modifications by end of reporting period.

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9 GLOSSARY t.

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GLOSSARY OF VARIOUS ABBREVIATIONS Page 1 of 3 1.

ABGTS

- Auxiliary Building Gas Treatment System 2.

ABSCE

- Auxiliary Building Secondary Containment Enclosure 3.

AB(I)

- Auxiliary Building (Isolation) 4.

AFW

- Auxiliary Feedwater 5.

AOI

- Abnormal Operating Instruction 6.

ASOS

- Assistant Shift Operations Supervisor 7.

AUO

- Assistant Unit Operator 8.

BAE

- Boric Acid Evaporator 9.

BAT

- Boric Acid Storage Tank 10.

BIT

- Boron Injection Tank

11. CAQR

- Condition Adverse to Quality Report 12.

CAR

- Corrective Action Report 13.

CBP

- Condensate Booster Pump 14.

CCP

- Centrifugal Charging Pump 15.

CCS

- Component Cooling System 16.

CCW

- Component Cooling Water 17.

CDWE

- Condensate Demineralized Waste Evaporator 18.

CRI

- Control Room Isolation 19.

CREVS

- Control Room Emergency Ventilation System 20.

CSS (CS) - Containment' Spray System 21.

CVCS

- Chemical Volume and Control System 22.

CVI

- Containment Ventilation Isolation 23.

D/G(s)

- Diesel Generator (t) 24.

DCN

- Design Change Notice 25.

DCR

- Design Change Request 26.

DR

- Discrepancy Report 27.

ECCS

- Emergency Core Cooling System 28.

ECN

- Engineering Change Notice 29.

EGTS

- Emergency Gas Treatment System 30.

EM

- Electrical Maintenance 31.

EMI

- Electromagnetic Interference 32.

EQ

- Environmentally Qualified / Environmental Qualification 33.

ERCW

- Essential Raw Cooling Water 34 E/ES

- Emergency Instruction 35.

ESF

- Engineered Safety Feature 36.

ESFA

- Engineered Safety Feature Actuation 37.

FCR

- Field Change Request 38.

FCV

- Flow Control Valve 39.

FDCT

- Floor Drain Collector Tank 40.

FDS

- Flow Differential Switch 41.

FIC

- Flow Indicating Controllers 42.

FSAR

- Final Safety Analysis Report 43.

FS

- Flow Switch 44.

FWI

- Feedwater Isolation 45.

GOI

- General Operating Instruction 45.

GPM

- Gallons Per Minute 47.

HDTP

- Heater Drain Tank Pump 48.

H0

- Hold Order 49.

IM

- Instrument Mechanic / Instrument Maintenance 50.

IMI

- Instrument Maintenance Instruction

GLOSSARY OF VARIOUS ABBREVIATIONS

+*

-Page 2 of 3 51 ~.

LCV

- Level Control Valve 52.

LER

- Licensing Event Report 53.

LCO

- Limiting Condition for Operation 54.

LOCA

- Loss-of-Coolant Accident 55.

LS.

- Level Switch

56..M&TE

- Measuring and Test Equipment 57.

mA

- M1111 ampere 58.

MAST

- Maximum Allowable Stroke Time 59.

MCR

- Main Control Room 60.

MDAFWP

- Motor-Driven Auxiliary Feedwater Pump 61.

MFI

- Main Feedwater Isolation 62.

MWF

- Main Feedwater 63.

MFWRV

- Main Feedwater Regulating Valves 64 MFP

- Main Feedwater Pump 65.

MI

- Maintenance Instruction 56.

MODS

- Modifications 67.

MOV

- Motor Operated Valve 68.

MSI

- Main Steam Isolation 69.

MSIV

- Main Steam Isolation Valve

70. MSR

- Moisture Separator Reheaters 71.

NE

- Nuclear Engineering (formerly Division of Nuclear Engineering) 72.

NIS

- Nuclear Instrumentation System 73.

NMUDI

- New Makeup Deionized System 74.

NSS

- Nuclear Security Service

75. NSSS

- Nuclear Steam Supply Systems 76.

O&PS

- Office and Power Stores Building 77.

PDS

- Pressure Differential Switch

'78.

PDIS

- Pressure Differential Indicator Switch 79.

PM

- Preventive Maintenance 80.

PMT

- Postmedification Test 81.

PORC

- Plant Operations Review Committec 82.

PORV

- Power-Operated Relief Valve 83.

PRO

- Potential Reportable Occurrence 84.

QMDS

- Qualification Maintenance Data Sheet 85.

RCS/(P) - Reactor Coolant System /(Reactor Coolant Pump) 86.

RHR

- Residual Heat Removal 87.

RM

- Radiation Monitor (RAD Monitor / RAD MON) 88.

RPI

- Rod Position Indicator 89.

RWST

- Refueling Water Storage Tank 90.

SCR

- Significant Condition Report 91.

S/D

- Shutdown 92.

SFP

- Spent Fuel Pit 93.

S/G(s)

- Steam Generator (s) 94.

S1

- Surveillance Instruction /or Safety Injection 95.

SMI

- Special Maintenance Instruction 96.

SOS

- Shift Operations Supervisor 97.

SOI

- System Operating Instruction 98.

SQN

- Sequoyah Nuclear Plant 99.

SR

- Surveillance Requirement / Source Range 100.

SSPS

- Solid State Protection System 101.

TACF

- Temporary Alteration Control Form - - - - - - _ _ _ _ _ _ _ _ _ -. _ _ _ _ _ -

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' GLOSSARY-OF VARIOUS ABBREVIATIONS Page 3 of 3 r

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'102. 'TI

- Technical Instruction i

103. TS(s).

- Technical Specification (s) 104. TVA

- Tennessee Valley Authority 105. UHI

- Upper Head Injection 106. UO/(S)RO - Unit Operator /(Senior) Reactor Operator 107. VLV

. - Valve 108. WP

- Workplan i

109. WR

- Work Request 1

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  • GLOSSARY OF VARIOUS' SYSTEMS Or SEQUOYAH NUCLEAR PLANT SYSTEM C00E SYSTEM TITLE 1

Main Steam System (Turbine) (MS2) 2 Condensate System (FW Heaters) 3 Main and Auxiliary Feedwater System 5

Extraction Steam System 6

Heater Drains and Vents System 14 Condensate Demineralized 15 Steam Generator Blowdown System 24 Raw Cooling Water System 27 Condenser Circulating Water 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 62 Chemical and. Volume Control System 63 Safety Injection 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 82 Standby Diesel Generator System 87 Upper Head Injection System 90 Radiation Monitoring System 250 AC/DC Low Voltage Power 268 Hydrogen Mitigation System

- < e,.s, OPERATIONAL MODES

% RATED AVERAGE COOLANT MODE THERMAL.P_0WER TEMPERATURE 1.

POWER OPERATION

> 5%

> 3500F 2.~ START-UP j[ 5%

j[ 3500F 3.

HOT STANDBY 0

> 3500F 4.

HOT SHUTOOWN 0

3500F> Tavg

> 2000F 5,

COLD SHUTDOWN 0

j[ 2000F 6.

REFUELING 0

<.1400F l

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