ML19257B616

Monthly Operating Rept for Dec 1968

ML19257B616
Person / Time
Site:	Haddam Neck File:Connecticut Yankee Atomic Power Co icon.png
Issue date:	01/14/1969
From:	CONNECTICUT YANKEE ATOMIC POWER CO.
To:
References
TASK-TF, TASK-TMR NYO-3250-30, NUDOCS 8001170787
Download: ML19257B616 (22)

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Q. )k (, :'/I' OPERATION REPORT E0. 68-12

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Document No.

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AEC Contract No. AT(30-1)-3250

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Onerations The plant was placed in serv'ce the 2nd and operated at a base load of -k9h MWe during the month with the following exceptions:

A load reduction to 400 MWe for about two hours was made on the 7th, the lhth and the 2hth for turbine control and stop valve testing.

All tests were satisfactory but problems were encounte, red in re-opening the right hand stop valve.

A load reduction to ~h00 MW occurred automatically on the 7th.

e The 1C vital bus inverter failed, causing the associated power cange instrument drawer to actuate the load runback circuitry.

Load was restored to normal after transferring to a back-up power supply.

A plant trip occurred on the 9th.

Following the nonnal res-toration procedures and trip cause investigation, the unit was returned to service approximately four hours later.

A plant trip occurred on the 17th.

During the critical approach following the trip cause investigation, problems were encountered with the rod control system. The startup was delayed until repairs could be completed.

The plant was returned to service the morning of the 16th.

A plant trip occurred on the 25th. The generator main disconnect switch failed to open during the trip and was found to have a jammed and frozen operating mechanica for one blade.

The investigation and attempted repairs to the disconnect switch resulted in an extended outage. This time was utilized for a lengthy trip cause investigation. The plant was returned to service the morning of the 26th.

A plant shutdown was conducted late on the 27th. A comprehensive investigation of the plant protective instrumentation was con-ducted in an attempt to uncover the cause of the previous four unexplained plant + rips.

Extensive checkouts were made following each trip, but the trip cause had not been identified.

The plant was returned to service the morning of the 30th.

The newly installed circulating water varming line was placed in service on the 2nd.

19L6'322 Plant Shutdowns experienced during December consisted of the following:

DATES DURATION NO.

(From - To)

(Hours - Min.)

REASON 40-1-40 12/1/68-12/2/68 25 h2 Maintenance and testing.

kl-1-41 12/9/68-12/9/68 3 - 34 Automatic plant trip (Abnormal Occurrence 68-19).

42-1-42 12/17/68-12/18/68 9 - hk Automatic plant trip (Abnormal Occurrence 68-21).

43-1-43 12/25/68-12/26/68 14 - 07 Autcmatic plant trip (Abnormal Occurrence No. 68-23).

kk-1-kh 12/27/68-12/30/68 49 - 47 Investigation of the unexplained plant trips.

Abnormal Gecurrences experienced during December consisted of the following:

NO.

DESCRIPTION 68-18 The incident occurred on the 7th. With the plant at nominal full power, the #3 vital bus. failed. Because there are four vital bussen with plant protective circuitry equally divided among them and because all trip signals (at full power) supplied from this bus form part of logic circuits, no plant trip occurred; however, a turbine load run-back was actuated from nuclear power range channel 33, and a-pressurizer solenoid relief.

valve (568) opened.when the power supply. failed.

s Vital bus #3 was cleared of all load feeders and its alternate

, power supply connected.

Loads were restored and the pressurizer.

solenoid. relief valve was closed (pressurizer pressure reached

-aa low point of 1855 psig). All trip signals and alarms were cleared.

Plant load 2s stabilized following the run-back until all con-ditions were verified normal.

Power was then returned to normal.

A failed transformer in the inverter was replaced and #3 vital bus was returned to its normal power supply.

68-19 The incident occurred on the 9th.

While operating at nominal full power, a plant trip occurred without apparent cause. All shutdown systems functioned nonmally to shut the plant down to 1916 323

the hot standby condition without assistance. The computer print-out of the sequence of events indicated that 1B trip breaker opened to initiate the trip action.

All main control board recorders and indicators were reviewed for abnonaal indication; the data logger sequence of events and post mortem was reviewed and compared to previous trip data for normal content; all generator and 3h5 KV protective relay targets were che.cked and verified to be normal for a trip from power; plant operating logs were reviewed and all personnel on duty were questioned to ascertain the trip cause.

In none of these instances could the slightest indication be found of any situ-ation that would have tripped the plant.

Because of a previous trip from an unknown source on the 18th of November (Abnormal Occurrence 68-16), the trip breakers had been thoroughly inspected and their overcurrent set points tested by the breaker vendor during the Thanksgiving shutdown.

The breakers were found to be in excellent condition both mechanic:lly and operationally. Also all plant trip circuits effective above 10 percent power had been tested by simulating power and injecting trip signals.

In all cases each circuit flf performed properly and was annunciated and data logged.

Based on these results, no attempt van made to check each trip circuit prior to returning to power.

However, visual checks of circuit viring vere begun and continued until the plant was returned to po.rer; additionally, the light circuits monitoring the trip breakers trip coil circuit continuity were checked to determine if these circuits could, under any condition, Dnpose sufficient load on the trip coils to cause them to actuate.

It was found that they could not.

A complete inspection was made in the reactor containment. No problems were found.

All plant systems and components vera inspected for normal operation and line-up; all electrical distribution and switch-gear was inspected, and all alt.rms and trip signals were cleared.

Since no plant problems could be found and since the area load requirements were great, the decision was made to return to power and continue the investigation at the next shutdown.

The reactor was taken critical and the generator phased on the line at 1605 Full power was attained at 1935 the same day.

68-20 The incident occurred on the 9th. While conducting viring checks to deteraine the cause of an unexplained reactor trip, the coil leads for time delay releys 62X-1A and 62X-1B (undervoltage. trip' of reactor coolant pump's breakers) were found discon

24

These relays are situated on the two reactor coolant pump busses and function to trip the two pumps on their respective busses should power be lost for the duration of their time delay. An operating order was issued to insure the breakers would be tripped in the event of a power loss before this condition could be corrected during the next shutdown. However, while off the line because of a plant trip, the coil leads were reconnected, the breakers placed in the test position and tested by simulatirsg loss of power (a test switch was used to de-energize the bus undervoltage relays 27-1A, lAl and 27-1B, 1B1 which initiates the time delay relay action).

The time delay was adjusted to ~60 seconds and all tests were completed satisfactorily.

68-21 The incident occurred on the 17th.

While operating at nominal full power, a plant trip occurred without app 3 rent cause. All shutdown systems functioned normally to shut the plant down to the hot-standby condition without assistance.

The turbine plant first-out trip cause annunciator indicated a reactor trip had initiated the action.

No other alarms were received from any system or circuit until after the trip.

Automatic act us by the plant shutdown systems were reviewed for correct operation. Main control board instrumentation was reviewed for normal indication and the plant was verified to be in a normal hot-standby condition with all systems, circuits and parameters functioning according to design.

Alarms received subsequent to the trip were reviewed and verified normal.

Generator and switchgear relay targets and switching actions were checked, recorded and verified to be as required by the trip.

In view of the fact that two trips from an unknown source had occurred within the previous month with identical plant responses--

so far as could be determined--a two-fold plan was initiated to continue efforts begun after the first unexplained trip and continued after the second one:

One was the physical removal and exchange (with each other) of the two plant trip breakers. These breakers had been tectc.i both electrically and mechanically with no evidence of malfunc-tion; however, the exchange of the breakers vaa to help pin-point the cource should any further trips occur.

In the first two trips (Abnormal Occurrences 68-16 and 68-19) the 1B trip breaker was recorded by the data loCger to open to initiate the trip; and, although the data logger was not in service during this trip, observed actions and indications were identical to the first two.

Therefore, by exchanging the breakers and maintaining the data logger in. service, if another trip occurs it should be possible to either eliminate the possibility or confirm the fact that thcse breakers are the trip source.

i9T6325 i

The other was the continuation of a wire-by-wire check of all plant protective instrumentation viring which could be the cause or could result in a plant trip.

Goveral loose viring connections were found and adjusted in the turbine protective circuitry, but, becauce a reactor trip occurred first, these are not con-sidered the trip cauce; however, a viring connection which is located on the turbine plant manual reactor-trip puch button and is in the power cupply to the undervoltage coils of the two trip breakers was found so loose that it simply disconnected when checked.

The trip breakers are equipped with two independent systems of tripping. A circuit which ic energized to trip (trip coil) and a circuit which in de-energized (undervoltage coil) to trip.

All normal plant trips actuate both, and either one vill trip

'the breaker.

Because the unexplained trips occurred with no protective relay alarms which would have been roccived had the trip circuit been energized, the undervoltage circuit was suspected as the trip cause; therefore, the loose viring con-nection in this circuit becomes extremely significant. However,,

the trip cause cannot be identified.

After completing the trip breaker exchance and coveral hours of viring checks and because the plant vna required by the cystem load demands the following morning, a plant startup vac begun at 2h00 the 17th. During the critical approach a problem developed with the controlling rod groups control circuitry (Abnormal Occurrence No. 22) and startup was delayed. The reactor vac brought critical at 03h3 the 18th. The generator was phaced at 0429 and full power achieved at 0800 that nornin6 68-22 The incident occurred on the 18th.

In conducting a critical approach, bank A control rods were selected and withdrawal commenced.

It vac immediately discovered that bank B rods were being withdrawn simultaneously although not selected.

Bods were then inserted.

Both banks showed inward motion.

The bank selector switch was switched from A to B and the same action was repeated. The rods were then fully inserted.

In checking out the rod control system equipment, a " memory" relay in the bank A overlap assembly was manually rotated one step.

Control of bank B rods was then checked and found to be nonnal; however, when bank A van selected, both banks moved as before.

Further checking revealed the command relay for bank B operation to be mechanically held in the energized position with the result that when bank A vas selected, the command reJays for both banks were energized which would permit rods in both bank.s to operate f9F6 326.

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on a stepping signal. The relay was removed and repaired by adjustment and reinstalled. Normal response of both banks was then verified several times.

The reactor vac brought critical at 0343 hours0.00397 days <br />0.0953 hours <br />5.671296e-4 weeks <br />1.305115e-4 months <br /> and the plant returned to service.

68-23 The incident occurred on the 25th. While operating at nominal full power, a plant trip occurred without apparent cause. The computer print-out of the sequence of events subsequent to the trip indicated 1B trip breaker had opened to initiate the action.

All shutdown systems functioned to shut the plant down to the hot standby conditions without assistance.

The nain generator disconnect switch failed during the trip and remained closed; however,.the plant was removed from the line by the main output breakers.

Automatic actions by the plant shutdown systems were reviewed and the plant was verified to be in a normal hot-standby condi,

tion. Main control board instrumentation and alarms were reviewed and verified norm,.1.

An investigation of the failed generator disconnect switch vac begun. A chear pin in the drive unit gear box was found to have sheared.

It was replaced but sheared again when an attempt was made to open the disconnect manually. The drive linkage was disconnected and attempts to open the individual switch blades were made.

Two blades were successfully opened; however, the third blade could not be opened - a third pin was sheared in the attempt.

It became apparent that complete disassembly of the linkage and gears to the stuck blade would be required; and, because this vould require a significant amount of time and personnel (which were not readily available), it was decided to reclose the blades and operate without benefit of the disconnect

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switch until further plans could be made.

Concurrently, a maximum effort was made to uncover the trip Tests were conducted'to pin-point which trip circuit cause.

was initiating the trip.

Because the trip breakers had been exchanged with each other following a previous trip and because this trip was initiated by the exchanged breaker, it was assumed that the breaker circuitry was not the cause of the trip.

Breaker response to an undervoltage trip was checked, as this circi, had been suspected following the last unexplained trip; in all tests the two breakers responded simultaneously hove',

c, to the trip signal.

It was therefore tentatively concluded that the trip coil circuit rather than the undervoltage circuit initiated the trip. Attempts were made to check this' theory, but conclusive results could not be reached./

On the assumption that the 1B breaker trip coil circuitry was the cause or at least the initiating circuit, a wire-by-vire check of the associated protective circuits was made. Over eighty percent of all wires were checked prior to terminating the effort (in this check, each contact and connecting terminal-- point to point--of each wire is checked). No single prob:em was encountered which would have resulted in the trip, although several minor discrepancies were noted and corrected. Additionally, a vire-by-wire check of the nuclear overpower and start-up-rate trip circuits was made and all relays in these circuits were visually inspected for contact position. No significant problems were discovered by these checks. Since only negative results had been obtained from the instru-mentation checkout, it was decided to resume operations following termination of efforts to repair the generator disconnect switch. The reactor was taken critical at 0202 the 26th and the plant was placed back in service at 0329 Full power was achieved at, about 0630 the same morning. 9I.6 328 7-

Maintenance Major items completed during December: Replaced the drive motor for the main generator disconnect switch 320-12d-5 Due to the limit switch setting, the old motor had overdriven and failed. Re-installed 1B chn ;ing pump motor, which had been sent out for balancing. The unit was aligned and placed in standby for emergency use only. The pump will be disassembled and the internal wearing parts will be exchanged for similar parts of a different material and a new shaft coupling installed prior to being returned to unrestricted service. Replaced a failed sola gransfonner in the "C" vital bus inverter. Adjusted and weighted the inlet air louvers to the energency, diesel generator room to prevent entrance of cold air except when the generators are in service. Replaced a casket in the #3 main steam lead-in pipe to the high pressure turbine. Replaced a bonnet gasket on the 1st point extraction steam non-return valve. Replaced the manvay gaskets on the A, B and C moisture separators. Installed a new bellows and new internal seals in the resi-dual heat removal system 500 psi relief valve. The valve lift pressure was checked on the test block. Inspected root valves on systens connected to the reactor coolant system for leakage and boron kdidup problems. The boron was removed from several valves and the packing glands, gland studs, nuts and pins were checked for acid corrosion. The gland support on two valves was found to be partially destroyed by the boric acid. Temporary repairs were made to these,and. 1 remaining valves found leaking were adjusted and the gland assembly coated with epoxy. Numerous valves connected to the reactor coolant system have carbon steel gland assemblics which are subject to rapid corrosion when in contact with boric acid. Additionally, some of these valves are fitted with " loose" back seats vice integral back seats; consequently, leakage past the back seats is more prevalent in those valves. It is planned to replace all carbon steel valve parts with stainless steel on a routine basis to eliminate this problem. I 9 I $ 'l ? 9

Installed a strainer in the concentrator supply and recirculation line. Re-aligned the 1B rod drive motor generator set and replaced the fly-wheel shaft bearing on the motor end. This is the third time this unit has required re-alignment due to exces-cive vibration and it appears the unit foundation may need strengthening. Additional investigation of the problem is planned. Conducted a point-to-point viring check of the 13 trip breaker shunt trip circuitry in conjunction with Instru-mentation. In order to minimize the time for this check, plans were fonnulated and the circuits divided among groups prior to shutting down. This arrangement resulted in reducing the time required for the viring check from an estimated 30 hours to an actual time of 14 hours. The viring check did not reveal the trip cause; however, it, 61d uncover several items which were corrected and are listed below: Several terminal connections were loose. One circuit in the first out annunciator system was found connected to the wrong terminal. A relay in the coolant flow trip circuitry had a contact which would not operate. An alana circuit for two of four pumps loss of flow in the first out alans circuitry was found to terminate at the wron6 terminal block. 4 1916 330 ~ l g l U w' b

10

Adjucted the fire protection air sensing cyctem for the main trancformer. This sensing air detects for trancformer fires and actuates the fire deluge system. However, due to censi-tivity of the system, the fire deluge has been actuated cubsequent to most plant trips, necessitating a lengthy reset process. Inctalled a system to provide vell vater as a back-up to the main circulating water pumps shaft bearings. This vill provide the necessary fluch and cooling water in the evcht filters in the present system become fouled. Repaired and modified three rod position indicating coil stacks. These were modified by removing the exterior alumi-num cans for tetter cooling of the coils. Installed a modified type fuse in the power supply to the control group of pressurizer heaterc. Full heater load was then re-established. These fuses were installed on the 9th, and no further failures have occurred. Reconnected and functionally tested the reactor coolant pump bus undervoltage time delay trip relays for the coolant pumpa' breakers. Made the following modifications and repairs to the aerated drains evaporator: Properly prepared the internal curfacec of the batch and distillate tanks and applied a coating of epoxy. Inctalled nececcary fittings required to raise the con-centrated "high vnter level detector" to prevent unnecessary unit snutdowns caused by foaming. Installed a strainer in the concentrator level control float column to prevent failure of the float to maintain IcVel. Re-routed the gas surge line (vent) from the batch and distillate tanks to the sample sink exhaust hood in the primary auxiliary building. Installed a union in the recirculating eductor to permit easier cleanout. Installed a chcracul addition funnel in the top of the batch tank. This vill permit addition of an anti-foamant to prevent excess foam in the concentrator. i9'l6"331 Instrumentation Major items completed during December: Three power range instrument drawers were replaced during the month: On the 5th, channel 34 began to give intermittent rod stop and channel deviation alarma. The drawer vaa replaced with the plant at full power. Repairs were then made to the drawer. On the 23rd, while conducting a regular bi-vcekly check, no load runback signal could be obtained from channel 32. The drawer van replaced at power. On the 25th, channel 32 gave no rod drop rod ctop signal when the plant tripped. The drawer was replaced prior to the plant startup. Relocated a 75 ohm equalizing recintor in each of four vital bus inverter cynchronizing circuits. The resistors were overheating adjacent components and endangering operation of the inverters. They were relocated to a terminal board within the inverter cabinet. Comp eted modifying thirteen of the twenty-five 63G elec-tronic alarm units located within the plant protective and alarm circuitry. This modification concists of replacing and relocating a capacitor which has had a high failure rate with an upgraded type. This is in accordance with the vendor's recommendation and with parta supplied by the vendor. There units are located in the steam dump actuation circuit, the auto rod control circuit, the rod stop permis-cive circuit, the low precoure trip calculator output circuit and in several protective alarm circuits; consequently, the modification is progreccing at a rate di'ctated by plant availability. Completed modifying six of the ten (eight installed) reciatance-to-current converters installed in the plant inctrumentation--loop Taverage and AT. This modification van cauced by a high failure rate and consists of replacing five capacitors in each unit with a higher quality capa-citor. The modification is being done at the vendor's request and with parts supplied by the vendor. hlb 332 Fabricated a face panel which vill indicate a failure in the steam dwr.p circuitry. Becauce thic circuit is not nor-mally in cervice, there vac originally no vay to detect a failed actuating unit within the circuitry. In a number of inctances steam dump actuation vac blocked during initial checkout because of a failed but undetected actuating unit. Fusco with failure indicating lights have been installed for each unit and vill be mounted on the panel with proper labeling to immediately identify which unit has failed. These fuoco have been and vill be checked at least once cach chift. Completed a point-to-point wire checkout of the 1B trip breaker chunt trip circuitry in an attempt to uncover the cause of the four unexplained plant trips. Conducted tects while shutdown to reproduce the simultaneous motion of control rod groups A and B as reported in Abnormal Occurrence 68-22. All tests demonstrated that the bank selector switch opened the circuit for the bank not colected. Only by simulating the failure of the bank B command r elay with bank A celected could the movement be reproducci. Conducted a complete comprehencive functional checkout of all plant trip circuits following completion of the point-to-point vire checks, viring continuity checkc and visual incpection of relayc in the 1B trip breaker chunt trip circuit. In each case normal responce vac verified by nain control board annunciatorc, reactor and turbine plant first-out trip annunciators, data logger print-out and trip circuit counters. Installed three seal-in type relays in the chunt trip circuit of 1B trip breaker. These relays divide the incoming trip cignals into three segmento. The first segment receives all trip signals effective above the P-8 power level permis-cive cetting (8h5); the second segcent receives those trip signals effective between the P-7 and P-8 permincive cettings ~ (10-8k%); the third segment receiven thoce trip signalc effective below the P-7 permiccive cetting (10%), except for the manual trips which bypasc all relays. These relays will seal in upon receiving a trip cicnal and send a signal to the data logger as well as pacc the trip signal on to the breaker trip circuit; additionally, the first relay to actuate vill lock out the other two. By negnenting the trip signals, the trip vill be identified as having originat'ed from a particular segnent and vill greatly reduce the. area of investigation. 1916 333 W W

Modified two power range nuclear instrument drawers by adding a capacitor between the drawer test switch and ground to prevent voltage transients when testing the rod drop rod stop circuit. In conducting this test the drawer is placed in test and a power signal is injected by a test pot, then the test switch is returned to operate. Previous to modi-fying the drawers, a voltage " spike" would occur when returning the drawer to operate which masked the test signal and. prevented determining the set point. The remaining drawers will be modified as time permits. Re-ceroed the four feed flow transmitters utilized for data logger calorimetric input signals. Continuing problems have been encountered with shifting of the static aligraent calibrations and zero differential output signals of these units. The vendor has been informed of the problem and is presently evaluating possible solutions. Chemistry Reactor coolant system boron decreased (average) from 1130 ppm to 1030 ppa during the month. A total of 16,500 gallons of water were processed through the ~ boron recovery evaporators during the month. All bottoms were returned to the boric acid mix tank for re-use. Early in the month tritium was identified in the component cooling system at a low and apparently equilibrium concentration. A program of feed-and-bleed was initiated to determine if in-leakage was occurring at a small rate or if some radioactive material entered the system during maintenance on the non-regenerative heat exchanger (Labor Day shutdown). The tritium decreased in proportion to the dilution rate; however, following the plant trip of the 9th, analysis indicated an in-leakage of about one gallon of primary coolant water. Since that time, the tritium level has decreased in direct proportion to the dilution rate with no further in-leakage detected. Tentative conclusions are that a snall pressure leak exists in one of the components supplied from the system. The tritium activity is being reduced by dilution to the lowest practicable level in order to more closely observe any leakage. The 1A water treatment domineralizer resin was given a manu-facturer's recommended treatment for iron fouling of the resin. At intervals of about one year of normal operation the resin bed capacity is I9i6.334 reduced by approxinately 50% and come cilica leaching begins to occur prior to bed exhauction. Normal regeneration is not effective and a cpecial recencration is nececcary. The treatment concicts of a 30% colu-tion of hydrochloric acid and appears to be effective in restoring full '.ad capacity. Representative reactor coolant analyces are as follows. WEEK ENDING 12/6 12/13 12/20 12/27 rh 0 25 C 6.40 6.45 6.h7 6.50 Conductivity (pnhoc/cm) 21.0 20.0 21 5 25 0 Cl- (ppm) <0.06 <0.06 0.06 0.06 Disco 1ved 02 (ppm) <0.05 <0.05 <0.05 <0.05 Loron (ppm) 1111 1076 1071 1055 Li+ (ppm) 1.4 1.h 1.4 1.38 Max. crocs activity (uc/cl) 1.6 x 10-1 1.4 x 10~l 1 3 x 10-1 1 5 x 10~1 Il 31 (pc/nl) 190 x 10~4 1.22 x 10-4 2.0 x 10-4 5 5 x 10~4 Max, tritium (pc/ml) 2.7 29 32 32 Crud ( m) 0.06 0.356 0.48 0.48 ~3 Il31/I 3 ratio (A) 3.26 2.83 h.3 6.76 Analysis of a typical crud cample for the month. 54 59 CoS8 Cr51 V.n pe s s 3.68 x 105 DPM/mg 1.03 x lo 5.30 x los 1.13 x lo I9l6'335 e i Henith and Sifety The cor.tainment humidity decreaced to a point which prevented normal tritium campics. An alternate method vac started in which the ? ne condensate is collected from o containment recirculation fan cooler. Thic method appears to be equally acceptable. A meeting van hela with a representative of the Middlecex Memorial Hospital to discuca handling of radioactively conte:r.inated patients. An t_nnual review of the plant emergency plan was completed. ~ Four men were given annual physical examination. during the month. 'The following environmental releases were made during the month: t Gaceous: ione Liquid: 84,800 gallons 99.38 me a y 19h.63 curies tritium The naximum rr.diation exposure ac measured by docimeter during the month was 206 mrem; the average for all plant personnel was ll.h trem. The maximum radiation level recorded during the month vac 16 R/hr. on contact with the ceal water return filter. Other reprecentative levels recorded were 400 mr/hr. on contact with the volume control tank and 200 mr/hr. on contact with the chemical and volume control system letdown line. Tne.. aimum contamination IcVel detected during the month 2 .eac 12,100 dpm/ft on the RCA chemistry laboratory hood. Other reprocen-2 tative cmears were 5,250 dpm/ft on the floor of 1B charging pump cubicle; 2 2 1,550 dpa/ft on the floor of 1A charging pump cubicle; 2,932 dpm/ft on the intermediate floor of the boron recovery system and 4,069 dpm/ft2 on the floor of the reactor containment. The chemistry laboratory hood was decontaminated to <5,000 dpm/ft2, 7.. Y9i6r336

Encincerini Core life vas calculated at 50% of design at the end of the month. Conducted a minimum of two hand secondary calorimetrics each veek for power control. Continued work or the plant " Fuel Accountability Manual". This manual should be complcted during January. Computer

• he computer expansion' program was completed during the month.

This increased the computer core capacity from 16,000 words to 24,000 words and added an additional out-of-core disk. The addition of the extrq, core capacity permits expanded applications of the computer as the need arises. The addition of the second disk added security to the system in the event a disk becomes damaged. Two problems renc#r as a result of the expansion: the automatic re-start feature following a, aver loss is not funcu aning and the response to computer-detected faults v s the error alert control program is not performing properly. The manufacturer is presently working to correct both problems. O e G Plant Performance PRIMARY The reactor performance vac normal throu ; bout the month. An s "all rods out" in-core flux cap was taken on November 17th. The manu-facturer's analysis of the in-core parameters is as follows: (No complete maps were taken during Dccember.) Power level IGith i lh60 Jeneter coolant prescure naig 2000 Core average temperature F 334 Rod height, nroun A st ens 320 Rod hoicht, Froun 3 ctenc l 304 '4aximun FAH nuclear 1.379 'hximum FAH total 1.462 l.673 Maximum Fc nuclear iXcximur Fq total i 1 740 l Core averarte Fz (nover) i 1.200 ! Core averace Fz (flux) i 1.209 lGuadrant flux tilt i 21.5 The boron depletion rate continues to be ~120 pps/MTU. GECONDARY The secondary plant performance during the month vac normal except for the 1D moicture-ceparator reheater. Repairs to this unit were completed on the lot and conaisted of plugging seven tubec and welding eroded areas at the tube enda of several more. The unit performed nor-- mally on plant ctartup the 2nd and continued for ceveral days; howcVer, at the end of one week of full power operation the crossover steam outlet temperature had begun to decreace clc.iy. Following the plant trips on the 9th and 17th, cignificant decreaces in outlet temperature were obccrved. By the end of the month the outlet temperature had decreaced from 458 F to L31 F and appearca to be holding at the final figure. Leakage from the high pressure turbine flange had increased to about two liters per hour by the end of the month. 1916 338 Typical end of month performance data for the condenser, feed water heaters and moisture-separator reheaters are tabulated below. / Condencer I L.P. ( Hrt") l .67-Temn. rice P l 19 1 Ave. inlet water temn. F 32.5 51.6 Avr. outlet water temn. F "A" cond. elean factor ! 104.3 "B" cond. clean factor 109 8 Feed Water Heater TTD e l F.W. Heater: ll A B l No. 1 TTD ( F) ll 25 l 25 No. 2 0.6 l h.6 I! 6.1 51 I:o. 3 li 6.1 l 3.8 No. 4 No. 5 !! 1:,.05 l 12.05 f 11 75 l 11.75 No. 6 Moisture Separator Reheaters l A l B C l D AP usic I! 10 I h 8 9 TTD F II36.0 30.2 33.6 ! 55 5 1916 339 8

Surveillance All checks, calibrations and tests required during the month have been successfully completed. Additional items required less frequently than monthly and which have been successfully completed during the month include: Six week tests of all pressurizer level instrumentation alarm and trip functions. Six week tests of all pressurizer pressure instrumentation alarm and trip functions. Design Changes There were no design changes completed during the month, a Plant Operating Procedures There were no changes to the plant operating procedures during the month. 1916 340

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