ML18025B137

Second Monthly Operating Rept for Sept 1980

ML18025B137
Person / Time
Site:	Browns Ferry
Issue date:	10/10/1980
From:	TENNESSEE VALLEY AUTHORITY
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ML18025B135	List: ML18025B134 ML18025B137
References
NUDOCS 8010160511
Download: ML18025B137 (123)

Text

TENNESSEE VALLEY AUTHORITY BROGANS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT BROWNS FERRY NUCLEAR PLANT SEPTEMBER 1980 Submitted By:

Plant Manager

-">>o;6 o5//

TABLE OF CONTENTS PART I Operations Summary Plant Operations Fuel Performance .

Refueling Information. 10 Equipment Performance. 12 Change in Procedures 16 Change in Facility Design. 16 Surveillance Testing 17 Containment Leak Rate Tests. 18 Changes, Tests, and Experiments Requiring Authorization from the NRC Pursuant to 10 CFR 50 59 ~ (a) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o 18 Changes in Plant Operating Organization. 18 Reports to NRC . 19 Changes, Tests, and Experiments Not Requiring Authorization from the NRC Pursuant to 10 CFR 50.59 (a) 20 Primary Coolant Chemistry.

Source Tests 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 22 Environmental Technical Specification Requirements 23 Calculation of Usage Factor. 23 PART II Important Events. 24 Vis i'to 1 s ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~

Safety and First Aid. 27

TABLE OF CONTENTS (Continued)

PART II (Continued)

Accidental'

~ ~ ~ ~ o ~ ~ ~ 27 Plant Personnel Listing. 28 Personnel Changes Annual 31 Personnel Changes Hourly . 37 Significant Operational Events 40 Plant Instruction Revisions. 45 Reportable Occurrences 46 Primary Coolant Chemistry. 49 Average Daily Gross Capacity Factor. 51 Accumulated Average Daily Gross Factor . 52 Radwaste Monthly Average Discharge Rate/Total Activity Discharged. 57 Building and Stack Monthly Release Rates 58 Specification Comparison Building 'echnical and Stack Release Rates 59 Reactor Power Percent. 60 Nuclear Plant Operating Statistics 63 Unit Outage and Availability 64 Outage Summary . 67 Electrical Maintenance Summary 68 Electrical Maintenance Summary Charts CSSC Equipment. 70 Non-CSSC Equipment. 73 Mechanical Maintenance Summary 76

I TABLE OF CONTENTS (Continued)

PART II (Continued)

Mechanical Maintenance Summary Charts CSSC Equipment 77 Non-CSSC Equipment 80 Instrument Maintenance Summary. 82 CSSC Equipment 87 Radioactive Liquid Effluents. 88 Airborne Releases Solid Radioactive Waste 96 Effluent and Waste Disposal Monthly Report. 100 Resin Usage . 101 Powdered Resins  % Total Usage . ~ ~ 102 BFNP Filter Demineralizer Performance 103 Fuel Cladding Integrity Parameters. 106 Waste Treatment System Volume Throughputs 108 Water Treatment Chemical Use. 109 Total Plant Training Summary. 110

PART I 0 erations Summar September 1980 Unft 1 Unit 1 was critical for 703.3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />, produced 699,320 MWH (gross) with 3.07 percent station use, resulting'n a average hourly gross load of 1,003,012 Kw during the month. The average net heat rate for the month was 10,950 BTU/KWH. There are 192 full power days estimated remaining until the end of cycle 3 fuel. With a capacity factor of 85 percent the target EOC exposure would be reached on May 10, 1981. This includes 0 days of coastdown. The capacity factor for the month was 88.4 percent.

There were two scrams on the unit during the month. On September 1, the reactor scrammed when water from the offgas cooler dripped onto the stator cooling cabinet causing a short in a pressure relay tripping the turbine. The reactor scrammed on September 24, when a short circuit occurred in the sudden pressure trip caosing the 500 KV circuit breakers to open which caus'ed a general load reject.

There were seven power reductions during the month. On September 3, power was reduced because of maintenance to the "C" string high pressure heaters. Power was reduced on September 7, 20, and 27, for turbine control valve tests and Sl's.

On September 16, power was reduced when "A" recirculating water pump was taken out-of-service to place the unit on cooling towers. Power was reduced on September 19, when the "B" reactor feedwater pump was taken out-of-service for maintenance for excessive vibration. On September 29, power was reduced for condensate de-mineralizer backwash and precoat due to problems on three of the condensate demineralizers.

0 erations Summar (Continued)

September 1980 Evaluation of Unit 1 cycle performance shows that the unit operated 10,620 BTU/KWH gross heat rate which is 0.88 percent higher than expected.

Unit 2 Unit 2 was critical 118.78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />, produced 113,120 NWH (gross) with 4.69 percent station use, resulting in an average hourly gross load of 952,349 kW during the month. The average net heat rate for the month was 10,850 BTU/KWH.

The EOC 3 refueling outage for Unit 2 began on September 5, 1980. The capacity factor for the month was 14.3 percent.

There was one scram on the unit during the month. On September 5, the reactor was manually scrammed in preparation for the beginning of the EOC-3 re-fueling outage.

There was one power reduction during the month. From September 1, to

'I September 5, power was reduced due to end of cycle coastdown to the EOC-3 refueling outage that began on September 5.

Evaluation of the Unit 2 cycle performance shows that the unit operated 10,350 BTU/KWH gross heat rate which is 2.72 percent lower than expected.

Unit 3 Unit 3 was critical for 654.2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, produced 625,700 MK (gross) with 2.98 percent station use, resulting in an average hourly gross load of 956,245 kW during the month. The average net heat rate for the month was 10,820 BTU/KWH. There are 31 full power days estimated until the end of

.cycle 3 fuel. With a capacity factor of 85 percent the target EOC exposure would be reached on October 31, 1980. This includes 26 days of coastdown.

The capacity factor for the month was 79.1 percent.

0 erations Summar (Continued)

September 1980 There were two scrams on the unit during the month. On September 12, the reactor was manually scrammed to begin a short maintenance outage on the "B" inboard main steam isolation valve. The reactor scrammed on September 20, when a 480 V shutdown board failed to transfer from alternate to normal feed pro-ducing a loss of RPS MG set and the isolation of a SJAE which caused a main condenser low vacuum.

There were seven power reductions during the month. On September 1, power was reduced when "A" recirculation pump tripped. Power was reduced on September 7 and 27, for turbine control valve tests and SI's. From September 7 to September 12, power was reduced when the closure time was found to be too fast on MSIV 1-26 and the valve was closed until a short maintenance outage on September 12. Power was reduced on September 23, for a control rod pattern adjustment. On September 24, power was reduced due to loss of the computer while performing preconditioning to full power.

Evaluation of the Unit 3 cycle performance shows that the unit operated at 10,550 BTU/KMH gross heat rate which is 1.42 percent lower than expected.

0 erations Summar (Continued)

September 1980 Reliabilit and Availabilit The accumulated average daily gross (AADG) capacity factors, based upon midnight IÃH meter readings, for each unit is tabulated below for each month during the last calendar year. The second column compares this year' performance with last year.

Unit No. 1 Unit No. 2 Unit No. 3 1979 1980 1979 1980 1979 1980 Jan *17.4

• 7.6 94.8 86.4 90.8 37.4 (28)

Feb 50.7

• 3.8 94.0 62.5 93.3 67.4 (29) 59.2 2.9 91.5 65.9 93 ' 77.8 (22)

Apr 67. 0 18. 1 *90.4 69.4 93.6 83.1 72.5 31.1 *72.3 72.9 90.5 84.1 June 75.7 38.9 72.4 73.1 85.0 84.2'uly 78.0 44.9 75.2 73.3 85.0 7.94 Aug 79.9, 51.0 77.7 75.0 *81.8 81.4 Sept 79.1 55.2 79.0 *68.2 *72.7. 81.1 (25)

Oct 80. 0 80.6 * *65. 5 Nc (39)

Nov 79.6 81.5 *59 '

Dec(') 80.1 79.5 *58.7

• Refuel Outage (Days of Month)

(1) Yearly Average Unit 1 can achieve an AADG capacity factor of about 62.7% for CY '80 if it averages 85% CF (presently averaging 77.8%) for the remainder of the year, considering unit operating time (i.e.: not in refuel). Similarly, Units 2 and 3 can reach about 64.8% and 73.0% AADG capacity factors, re-spectively. Presently these units are averaging 75.0% and 81.1%, respectively.

0 erations Summer (Continued)

September 1980 Reliabilit and Availabilit (Continued)

The largest capacity factor loss (12%) this month was on Unit 3 due to an inoperable HSIV (1-26 "B" inboard valve). This valve was closed and limited to 75% power for about 5.8 days.

The next largest CF loss (Unit 1 ~ 4.9%, Unit 3 = 2.9%) involves automatic scrams caused by equipment malfunctions. A significant controllable CF loss involved control rod pattern limitations on unit 1 and 3 at 0.8% and 1.7% re-spectively. These losses result from postponing rod pattern adjustment until weekends when more favorable system load requirements exist.

l, RELIABILITY AND AVAILABILITY(CONTINUED)

CAPACITY FACTOR LOSSES September 1980 Unit 1 Unit 2 Unit 80.1% 88.4 79.5% 14.3 58.7% 79.1 Losses were caused by:

l. Refueling 5.5 9.5 83. 6 29.3

2. P CION 2.8 1.9 2.5 1.8 2.1

3. End of cycle coastdown 1.4 0.2 2-. 1

4. Feed piping failure 1.4

5. Startup testing 0.9 0.5 1.0

6. Administrative limitations 0.8

7. Steam tunnel temperature switches 0.7

8. Reactor feed pump maintenance 0.6 ;0.6 0.6 1.3

9. High condenser backpressure 0.6 1.8 0.1 0.3 0.2

10. Thermal limits 0.5 I

11. Recirculation pump motor bearing problems 0.5 I 3.9

12. Automatic scram 0.5 >4.9 .0.6 0.8. 2.9

13. Drywell air leakage 0.4

14. Reduced thermal limits 0.4

15. Turbine vibration and balancing 0.3

16. Heater problems 0.3 0.2

17. Hoisture separator high level 0.3

18. Recirculation pump starting problems 0.3 0.2

19. Feedwater control problems 0.2 0.8 0.1

20. EHC and turbine valve problems 2.2 0.2

21. THI related modifications 1.5

22. Recirculation system vibration evaluation 0.6

23. Hain steam valve maintenance 0.'3 12;0

24. Recirculation H-G set brush changes 0.3

25. Rod sequence exchange 0.6 0.2 0.2

26. TIP system 0.2 0' 0.2

27. CMf system hydrogen sensor failure 0.5

28. Offgas system malfunction 0.3

29. Power cable replacement 0.3

30. Testable check valve maintenance 0.2

31. Load following demonstration test

32. Demineralizer problems 0.2

33. Low pressure air line break 0.1

RELIABILITY AND AVAILABILITY(CONTINUED)

CAPACITY FACTOR LOSSES September 1980 Unit 1 Unit 2 Unit 3 80.1% 88.4 79.5% 14.3 58.7% 79.1 Losses were caused by:

34. Rod pattern, full core flow 0.8 1.7

35. Surveillance instruction 0.1 0.1

36. Recirculation pump trip 0.4

37. Feedwater system leak 0.9

38. Control rod adjustment 0.2

0 erations Summar (Continued)

September 1980 Common The radwaste system performed as designed. Approximately 7.58E+05 gallons of waste liquid were discharged containing approximately 1.36E+00 curies of activities. Floor drain system through-put increased this month primarily because of decontamination activities associated with the unit two refueling outage.

Radwaste shipments to Barnwell, S. C. were interrupted for approximately 8 days due to a delay in the receipt of the required state shipping permit.

There were 14 shipments for an approximate total volume of 5,600 cubic feet.

There were 399 (55 gallon) drums of radwaste generated during the month at an average rate of 13.3 drums per day. There were 33 boxes of trash and irradiated components generated during the month at an average rate of 1.1 boxes per day.

0 erations Summar (Continued)

September 1980 Fuel Performance Unit 1 The reactor was operated at a nominal maximum thermal power level of 99.2% of rated. Typical thermal limits for this condition include CMFLPD, 0.973; MAPRAT, 0.945 and CMFCP, 0.885. The reactor operated in control rod sequence "A" 12 days, and in sequence "B" the remainder of the month.

Fuel preconditioning at the rate of 0.11 kw/ft/hr was conducted for approximately 1.4 days in sequence "A", and 3.1 days in sequence "B".

Unit 2 The reactor was operated at a nominal maximum thermal power level of 90% of rated. Typical thermal limits for this condition included CMFLPD, 0.731; HAPRAT, 0.730; CMFCP, 0.810. The reactor operated in control rod sequence "B" for the entire month.

Fuel preconditioning at the rate of 0.11 kw/ft/hr was conducted for approximately 0 days in sequence "B".

Unit 3 The reactor was operated at a nominal maximum thermal power level of 99.2% of rated. Typical thermal limits for this condition CttFPLD, 0.850:

MAPRAT, 0.827; and CMFCP, 0.965. The reactor operated in control rod sequence "A" for 14 days, and in sequence "B" the remainder of the month.

Fuel preconditioning at the rate of 0.11 Kw/ft/hr was conducted for 1.5 days in sequence "A", and 3.5 days in sequence "B".

10 Operations Summary (Continued)

September 1980 Refuelin Information Unit 1 Unit 1 'is scheduled for its fourth refueling beginning on or about April 15, 1981, with a scheduled restart date of July 25, 1981. This re-fueling will involve loading additional 8 x 8 R (retrofit) fuel assemblies into the core, the final fix on, the sparger modification, power supply on LPCI modification, and torus modifications if all approvals are received.

There are 764 fuel assemblies in the reactor vessel. The spent fuel storage pool presently contains 550 spent 7 x 7 fuel assemblies, five 8 x 8 fuel assemblies, and one 8 x 8 R fuel assembly. Because of modification work to increase spent fuel pool capacity to 3471 assemblies, present capacity is limited to 1152 assemblies.

Unit 2 Unit 2 is presently in its EOC 3 refueling outage. Unit 2 is scheduled for its fourth refueling beginning on or about March 1, 1982, with a scheduled restart date of June 14, 1982. This refueling outage will involve completing relief valve modifications, torus modifications if all approvals are received, "A" low pressure turbine 'inspection, and loading additional 8 x 8 R fuel assemblies into the core.

There are 764 fuel assemblies in the reactor vessel. At the end of the there were 132 discharged cycle 1 fuel assemblies, H+'onth, 156 discharged cycle 2 fuel assemblies, and 352 discharged cycle 3 fuel assemblies in the spent storage pool. The present storage capacity of the spent fuel pool is 820 assemblies. With present capacity, the 1979 refueling was the last

Operations Summary (Continued)

September 1980 Refuelin Information Unit 2 (Continued) refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.

However, new high density storage racks are being installed during the third refueling of Unit 2.

Unit 3 Unit 3 is scheduled for its third refueling beginning on or about November 2, 1980, with a scheduled restart date of December 11, 1980. This EOC-3 refueling, involves loading additional 8 x 8 R (retrofit) assemblies into the core, and power supply on LPCI modification.

There are 764 fuel assemblies presently in the reactor vessel. There are 144 discharged cycle 2 fuel assemblies, 208 discharged cycle 1 fuel assemblies, and 164 new P 8 x 8 R assemblies in the spent fuel storage pool. The present storage capacity of the spent fuel pool is 1528 assemblies. With present capacity, the 1980 refueling would be the last refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.

12 0 erations Summar (Continued)

September 1980 E ui ment Performance On September 16, at approximately 1730 hours0.02 days <br />0.481 hours <br />0.00286 weeks <br />6.58265e-4 months <br />, localized flooding was ex-perienced in the yard in front of the radwaste and the unit 1 and 2 diesel building. The flooding began during an attempt to place Unit 1 on cooling towers. Gate lA1 was closed and the resulting back pressure forced open a cover-plate sealing the top of the CCW conduit. Opening gate 1Al halted the flow of water into the yard area. The cover-plate on the Unit 1 conduit has been securely refastened.

While performing leak checks on 2D RHR heat exchanger, it was discovered that a check valve in the raw service water charging connection to RHR service water was stuck open. This allowed a leak test on 2D RHR heat exchanger to be interpreted as positive indication of leakage because it placed 2D RHR heat ex-changer (RHR side) in communication with RHRSW through 2B RHR heat exchanger which was known to be leaking. The check valve was repaired and a satisfactory leak check of 2D RHR heat exchanger was performed.

Unit 1 Reactor Building Equipment Drain Sump Heat Exchanger was determined to be providing inadequate cooling for the contents of the Reactor Building Equip-ment Drain Sump. This was indicated by steam rising through the sump pump support plate. Investigation thus far points to inadequate cooling water flow from RBCCW to the sump heat exchanger. This investigation continues.

13 0 erations Summar (Continued)

September 1980 E ui ment Performance (Continued)

High vibration on 1B Reactor Feedwater Pump was noted during routine weekly vibration checks this month. Increased surveillance revealed a high axial vibration level initially. This then shifted to high horizontal vib-ration at a frequency two times the pump run speed. As this is indicative of misalignment and the vibration levels continued to become more severe, the pump was removed from service and the coupling disassembled. It was found that all of the oil had been thrown out of the coupling. The oil was replaced and the pump returned to service without further problems.

Prior to the beginning of Unit 2 refueling outage, performance checks on both spent fuel storage pool cooling pumps for Unit 2 determined both pumps to be performing at less than 85% of their design capacities. Both pumps were rebuilt and subsequently performed at greater than design criteria.

High differential pressures were experienced on 2B reactor water clean-up filter demineralizer. Investigation revealed that a failure of the stainless steel filter elements allowed precoat material to accumulate on the resin trap.

The problem was corrected by replacement of the filter elements and associated resin trap.

Resin traps on reactor water clean-up demineralizers 1A and 1B were removed I

and examined to determine the cause of high differential pressure. An accumulation of rust was found on the traps. The source of the rust is still under investigation.

There was no indication of problems with filter element integrity. New resin traps were installed and the demineralizers were successfully returned to service.

14 0 eration Summar (Continued)

September 1980 E ui ment Performance (Continued)

Problems were experienced with the condensate demineralizers on Unit 1.

Failure of the filter element on vessels J and E allowed resin to accumulate on the downstream resin traps. High differential pressure across the resin traps forced replacement of the traps along with the failed filter elements.

The reason for unusually short service runs on vessel 1D was investigated. The vessel's filter elements were found to be severely fouled with iron oxide. It is believed the fouling resulted from improper precoating techniques which failed to protect the element with an over-lay of resin. The fouled elements were re-placed and the vessel was satisfactorily returned to service. Precoating records are being reviewed to determine if additional corrective action is warranted.

A visual inspection was made of the Unit 2 CCW tunnel on September 17, 1980. Algae growth covering approximately 10% of the wall surface (bottom and sides) of the tunnel was noted. The floor of the tunnel was covered with silt and mud that ranged from 1/2 inch to 2 inches in thickness. At the intake butterfly valves, there was approximately 1.5 ft3 of clams accumulated in the discharge from CCH pump B. At the inlet to the water boxes, there was approximately 0.5 ft3 of clams scattered around the tunnel floor.

TIP problems on Unit 3 affected the ability to establish full power rod patterns throughout the month of August. Problems with two of the five TIP machines resulted in fewer TIP sets being run than otherwise would have been run.

Detector "A" was replaced on September 22, 1980, and a PORC approved PMR was completed to eliminate problems with "D" machine. At the end of the month, all five TIP machines were operational.

0 erations Summar (Continued)

September 1980 E ui ment Performance (Continued)

The plant purchased a helium leak detection instrument to check the integrity of the main condensers. The instrument was not fully operational in time to check the Unit 2 condensers at the start of the refueling outage.

A leak check on the Unit 2 condenser is planned prior to the end of the outage when condenser vacuum is re-established.

18 0 erations Summar (Continued)

September 1980 Containment Leak Rate Tests

'rimary containment penetration leak rate tests were performed during the month. The results are within technical specification limits and are listed in the following table.

Leaka e (scfm T e Test Unit 1 Unit 2 Unit 3 Type A (integrated containment) No Test Incomplete No Test Type B (Drywell/torus hatches) No Test 0.0011 Personnel Air Lock (X2) 0.2119 Equipment hatches Electrical Penetration (X107B) 0.0173 Type C (Isolation valves) No Test 0.3236 No Test Totals 0.0 0.3420 0.2119 Chan es Test and E. eriments Re uirin Authorization From the NRC Pursuant to 10 CFR 50.59 a)

There was one revision to the Unit 3 Technical Specification comprised of pages ix through xxxi EPL 1 through 22, 156, 157, 170 and 171. Inoperable time was changed from 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> to 10 days on standby coolant supply capability.

Chan e in Plant Or anization There was one change to the plant staff for those positions designated as key supervisory personnel positions in the Technical Specifications.

A Plant Shift Engineer, M-4, was selected as Plant Assistant Operations Supervisor, M-4.

19 0 erations Summar (Continued)

September 1980 Re orts to NRC There were 23 reportable occurrences, a revision to one of these, and 2 cancelled reportable occurrences were reported to the NRC during the month.

20 0 erations Summar (Continued)

September 1980 Chan es Tests and Ex eriments Not Re uirin Authorization from the NRC Pursuant to 10 CFR 50.95 (a S ecial Test 186 "Scram Discharge Volume (SDV) Drain Valve Closure Pressure on Loss of Control Air Unit 2" This test was performed to determine the control air pressure at which the SDV drain valves would drift shut on a loss of control air. It was originated to aid in the evaluation of the potential for flooding the SDV as a result of a decrease in control air pressure.

STEAR 80-20 "I and C Bus A and B Load Current Determination" Test involved measuring current to various branch circuits feeding from I and C bus A and B. Data was submitted to EN DES to be used in their eval-uation of the voltage reliability analysis performed for these buses. This was in response to NRC inquiries.

Plant modifications will be submitted in the annual report.

21 0 erations Summar (Continued)

September 1980 Primar Coolant Chemistr Unit 1 The conductivity of the reactor coolant exceeded technical specification and fuel warranty limits for a total of 30.1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> during the month. A rup-tured tube in Cl waterbox and transients associated with Scrams 135 and 136 were responsible for the conductivity increases. Chloride concentrations and pH of the reactor coolant remained within technical specification and fuel warranty limits during the month. This calendar year the technical specifications and fuel warranty limits has been exceeded for 140.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br />.

Unit 2 The" conductivity of the reactor coolant remained within technical speci-fication,and fuel warranty limits for the month. Chloride concentration and pH of the reactor coolant remained within technical specification and fuel warranty limits during the month. This calendar year technical specification and fuel warranty conductivity limit has been exceeded for 71.3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />.

Unit 3 The conductivity of the reactor coolant remained within fuel warranty limits during the month. The conductivity of the reactor coolant remained within technical specifications of 2.0 pmhos during the month. Chloride concentration and pH of the reactor coolant remained within technical specification and fuel warranty limits during the month. This calendar

22 0 erations Summar (Continued)

September 1980 Primar Coolant Chemistr year the fuel warranty conductivity limit has been exceeded for 27.55 hours6.365741e-4 days <br />0.0153 hours <br />9.093915e-5 weeks <br />2.09275e-5 months <br />, and technical specification limit has been exceeded for a total of 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

Source Test None

23 0 erations Summar (Continued)

September 1980 Environmental Technical S ecification Re uirement

-

The raw water chlorination system was not operated during the month of September.

Reservoir water temperatures exceeded technical specification limits on two different days during the month of September. On September 28th and 29th the temperature rise was 5.1'. The average intake water temp-erature for the month was 83.6'., The largest water temperature rise was 5.1', with an average downstream water temperature of 85.3'.

Approximately 700,000 gallons of water was released from the unlined pond to the Tennessee River. The pH of the release was maintained within technical specification limits of 6.0 to 9.0.

Calculation of Usa e 'Factor The cumulative usage factors for the reactor vessel are as follows:

Location Usa e Factor Unit 1 Unit 2 Unit 3 Shell at water line 0.00487 0.00369 0.00314 Feedwater nozzle 0.23254 0.11570 0.15822'.12899 Closure studs 0.19566 0.09194

24 0 erations Summar (Continued)

September 1980 Im ortant Events September The Plant Manager and the Plant Operations Supervisor attended a briefing on Division Plan to Compensate Nuclear Power Employees and an Operator Staffing Presentation in Chattanooga.

The Plant Manager attended the Bi-Weekly Plant Manager Meeting in Chattanooga.

879 A Plant Outage Civil Engineer and a Plant Outage Electrical Engineer attended a meeting in Knoxville, on the Post-Accident Sampling Facility.

15-19 The Plant Chemical Unit Supervisor taught a chemistry and radio-chemistry course at the Power Operation Training Center for the STA's.

15-30 Two Plant Chemical Engineers attended an engineering training course at the Power Operation Training Center in Chattanooga.

The Plant Manager attended a meeting in Chattanooga on recommendations from Management Training Committee for M position profile plan.

The Plant Acting Compliance Supervisor attended a meeting in Chattanooga on IE Bulletin 79-01B.

19 The Plant Systems, Analyst attended a meeting in Huntsville, AL.,

with Chattanooga Central Office personnel and PIC Systems, Inc.,

to review the design of the PRIME/GE 4020 link.

A meeting was held at the plant between EN DES Knoxville, personnel, and the Plant Instrument Maintenance personnel to discuss power sources for the Feedwater Control System.

The Plant Outage Director attended a meeting in Chattanooga on Instrumentation Sensing Lines.

20 The Plant Acting Compliance Supervisor attended the NRC Region II, meeting in Atlanta on NUREG-0660 clarifications/TMI Action Plans.

22 The Plant Manager and representatives from the plant Co-op group attended a "kick-off" for combined 'Federal Campaign at the Marshall Space Flight Center in Huntsville, AL.

25 0 erations Summar (Continued)

September 1980 Im ortant Events September 22-25 The Plant Mechanical Results Unit Supervisor, the Plant Equipment Diagnostics Engineering Associate, and a Plant Mechanical Engineer attended a Vibration Training Class in Chattanooga.

23-24 The Plant Manager attended a Nuclear power Quality Meeting in Chattanooga.

24 The Plant Outage Director attended a Division Meeting in Chattanooga.

25 The Plant Manager and representatives from the Plant Co-op group attended the- United May "Kick-off" dinner in Huntsville, AL.

30 The Plant Quality Assurance Supervisor attended a QA Supervisor Meeting at the Power Operation Training Center.

The Plant Manager, the Plant Electrical Maintenance Supervisor, a Plant Shift Engineer, and two Plant Outage Electrical Engineers attended a meeting in Knoxville on Browns Ferry Nuclear Plant Under-voltage Modifications.

The Plant Outage Refuel Floor Coordinator attended a meeting in Chattanooga on Multi-Stud Tensioners.

Visitors September Mr. Dale Nix, Plant Engineering Staff; Mr. Frank Kelly, Reactor Engineering Staff; and Mr. C. D. Evans, EN DES Knoxville, met with the Plant Chemical Supervisor concerning PASF and revised design criteria.

Mr. Tom Hall, London Nuclear Services, was onsite to meet with the Plant Assistant Outage Director and the Plant Outage Drywell Coor-dinator, concerning chemical decontamination of CRD scram headers.

Mr. Barry Smith, General Electric Customer Service Plant and AMPS, met with various plant section supervisors.

Representatives from the Hewlett-Packard Corporation met with the Plant Chemical Supervisor to demonstrate the HP 9845 for PASF.

0 erations Summar (Continued)

September 1980 Visitors September Ms. Marilyn Taylor, Director of Personnel, was on site to meet with employees regarding various employee concerns. Her visit was a result fo Chairman Freeman's visit in July when questions regarding personnel were addressed to him. Job surveys were performed at nuclear plant positions by members of Ms. Taylor's staff and representatives of the Division of Nuclear Power personnel office. The results of these surveys will be compared to job surveys to be performed at a fossil plant.

4-5 Messrs. Ralph Thompson, Charlie Howell, and Frank Garrett, Chattanooga Industrial Safety and Fire Protection Engineering Staff was onsite to conduct an air flow test Unit 1 Reactor Building.

8-11 Office of Power Quality Assurance auditors were onsite to audit special processes and maintenance activities.

10-12 General Electric representatives were onsite to meet with the Plant Manager concerning HPCI and RCIC performance.

A 5-man team from Occupational Health and Safety was onsite to audit the outage operation.

12 Mr. Ron Westbrook, IS and FPE Supervisor, CHattanooga, was onsite for a Safety Inspection Audit Exit Meeting.

15 Two NRC licensing personnel were onsite to administer reactor operator and senior reactor operator licensing examinations to 10 Browns Ferry operators.

15-18 Three representatives from PLC (Professional Loss Control, Inc.)

were onsite to perform an audit of the fire protection system as required by technical specifications.

16 An NRC inspector was onsite to audit the inservice program.

22-25 Representatives from the Division of Occupational Health and Safety conducted a safety audit of outage work.

23 Mr. Marvin Lane, Executive Vice Pr'esident of Graver Water Company, met with the Plant Results Section Supervisor and others on the problems of contaminated powdered resins.

23-26 Office of Power Quality Assurance auditors were onsite to perform an audit of document control and technical specifications.

27 0 erations Summar (Continued)

September 1980 Safet and First Aid The regular weekly safety meetings of salary policy and trades and labor groups were held this month.

Accidents There were 2 loss-of-time accidents during the month of September.

28 NUCLEAR PLANT PERSONNEL Browns Ferry Nuclear PLANT End of End of Previous Present TITLE Month Changes Month Power Plant Superintendent~ M-8 Assistant Power Plant Superintendent M 6 Records Officer SA-2 eosIMst Mechanical En ineer SD-3 S ecification En ineer SD-3 En ineerin Aide SE-2 Safety Engineer SO 3 ngzneer ng i e Sa ety SE-Su ervisor, Mana ement Services Section M-5 Su ervisor Administrative Services hbck Unit H-4

~fctttsttgtttofstetocMZ Su ervisor Document Control Unit H-

~otaotctNsttgLeffttttxtnTgtrimst7BItsd Su ervisor Plt Services Unit H Secretar SB.4

>tlaarttISmNcgtgtPtorILM- Editor SA-2 Clerk Typist SB 3 15 Clerk-Typist SB 2 zfftetsofrftsfcs88.8 Clerk SB-2 Payroll Clerk SB 5 Pa roll Clerle%8Q<

Payroll ClerleSBR SB-3 File Clerk SB.3 Supervisor Services H-4 Su ervisor Qualit Assurance Stalf M 5 Qualit Assurance En ineer SO 4 Quality Assurance Engineer SO-3 Quality Assurance Engineer SO 2 Engineering Aide (Quality Assurance) SE 5 En ineerin Aide (Quality Assurance) SE.4 n ineerin Aide ualit Assurance) SE-3 lerk, SB-3 ail Clerk SB-2 Power Plant Results Supervisor M.5 Assistant Power Plant Results Supervisor M4 ower Plt Maintenance Supvr (Inst) H-5 Instrument Engineer SO 4 IfecuttttgtfrBI@tttmtcs88 Personnel Clerk SB-4 otttramstBBM S stems Anal st, SD-3 enior Instrument Mechanic Instructor Irgtmtdge8agtsrtttt~".ItttL(saacsflsft Programming Technician SE-4 Engineering Aide SE 3 Senior Instrument Mechanic Foreman 15 16 Senior Instrument Mechanic 44 43 Instrument Mechanic Instrument Mechanic Ap rentice- '4th Pd. 22 27 Instrument I'ftechanic Apprentice- 3rd Pd. 10 ctsrssrotttuntnhtacttmt(enectprzmfeme Pthc Nord Processor SB-4 sst. Power Plt. Maintenance Supervisor (Inst) M-4 Reactor En ineer SO 4 5U@tnBmjNI@SttgO7B Clerk SB-4 Engineering Aide (Nuclear) ZSA SE-5 TAMNQNSBrp;IftmttSGAz Supervisor, Mechanical Unit M-4 Mechanical En ineer SO 3 Engineerin Aide(Statistician)BRA SE-5 ttgfotroc'otg7rtfsfm(lamISr18ntaias)ISED Data Entry Clerk SB-2 Engineering Aide (Test Bt Studies) SE.3 TVA 7037 (PP-10.77) sheer 1 M mn,r September >>80

29 NUCLEAR PLANT PERSONNEL Browns Ferr Nuclear PLA14T End of Eno of Previous PfeSenl T IT t.s Month Chonoes Montn Mechanical En ineerin Associate SE 6 En ineerin Aide (Mechanical) SE 4 En ineerir. Aide (Mechanical) SE-3 En ineerin Aide (Instrument) SE.

En ineerin Coo Student (N) SE.3 Enoineerin 'Coo Student OQXZSZ (M) SE-3 Supervisor Chemical Unit if-4 Chemical En ineer SO 4 Chemical En ineer SO 3 Chemical Enoineerin Associate SE 6 Radiochelnical Laboratory Analyst SE 5 Radiochemical Laboratory Analyst SE 4 Chemical Laborator~ Anal st SE 3 Engineering Coop Student (C) SRR SE-4 En ineerinn Coo Student (C) SE.2 +1 -1 Radiochemical Laborato Anal st Tr SE-3 Su ervisor Reactor Unit M-4 Power Plant Operations Supervisor M 5 Assistant Power Plant Operations Supervisor M.4 Clerk SB 3 Shift Engineer M-4 16 15 Assistant Shift Engineer M-3 Assistant Shift Engineer-SR L 15 15 Unit Operator Unit Operator-RL 20 Assistant Unit Operator Student Generating Plant Operator- th Pd.

tu ent eneratxng ant perator r Clerk SB-2 Supervisor Janitorial Services i'-3 Janitor SF 3 Janitor SF 2 +17 -4 17 Janitor SF.l 55 +27 -20 62 Power Plant Maintenance Su ervisor E M-5 Power Plant Maintenance Supervisor M 5 Assistant Power Plant Klaintenance Supervisor (E) M 4 Assistant Power Plant Maintenance Supervisor (M) M 4 General Electrical Foreman M-4 Electrical Engineer SO 4 Electrical En. ineer SO 3 General Mechanical Foreman M-4 Mechanical Engineer SO.4 Mechanicaf En ineer SO 3

&rJcttacthsgtt(:cttxftfzstutstnt)Ms'echanical Engineer SD-2 En ineerin Aide (41echanical) SE 3 Engineering Coop Student (M) SE.

Xmxnnmsmmm~unx!&SR En ineerin Aide Electrical SE-Electrician Foreman 10 10 Electrician 46 + . -2 Electrician Apprentice- Pd.

Electrician Apprentice- 1st Pd. B 10 Electrician Apprentice- 1st Pd. A TVA 7OS7 (PP tO 77) Sheet 2 September,(0

30 I'JUCLEAR PLANT PERSONNEL PLANT end or End or Previous Present TITLE Month ChangeS Month Machinist Foreman Machinist Machinist Welder Machinist A orentice- 4th Pd Machinist Apprentice- 3rd Pd.

Machinist Apprentice- 2nd Pd.

Hachinist A I7rentice 1st Pd. B Hachinist A rentice 1st Pd. A Boilermaker Foreman Boilermaker Boilermaker Welder Boilermaker Apprentice- Pd.

Boilermaker Apprentice- Pd.

Sheetmetal Worker A rentice 1st Pd. A Steamfitter Foreman Steamfitter 24 Steamfitter Welder Steamfitter Ap rentice- 5th Pd Steamfitter'Apprentice- 1st Pd. A 12 12 General Labor Foreman H-3 Car enter Foreman Asbestos Worker Foreman ainter Apprent3.ce st P . A Structural Ironworker Sheetmetal Worker Foreman Sheetmetal Worker Asbestos Worker Car enter Painter Foreman Painter Heavy Equipment Operator-Power Labor Foreman Nuclear Plant Laborer 23 23 Truck Oriver I Sign Painter Total Annual Salary Policy 233 +67 -33 267 Total ATL Operations 112 + 7 -13 106 Total ATL Maintenance Total Plant 660 +91 -60 691 Hourly-List Titles Car enter 23 Car enter 1 Construction Laborer 71 Hortar Hixer 1 63 +12 Boilermaker (10) Hach Wldr (1) Steamfitter 15 20 26 Hach 28 Bricklaver 1 Painter 13 Asbestos Worker 2 Crane 0 erator 2 Sheetmetal Worker 3 Truck Driver I 2 Total Hourly 152 TVA 7037 (PP.10.77) Sheet 3 Month or

L 0

31 Se tember 1980 Personnel Chan es Annual Name Title Effective Date Betty J. Grimes Janitor F01 09 02 80 Billy J. Allen Janitor F01 09 03 80 Kenneth E. Howard Janitor F01 09 03 80 Richard L. Ingram Janitor FOl 09 03 80 William C. Jones, Jr. Janitor FOl 09 03 80 Arthur L. Littleton Janitor FOl 09 03 80 Jose I. Lozano Janitor F01 09 03 80 Michael E. Maples Janitor F01 09 03 80 Margaret L. Reach Janitor FOl 09 03 80 Larry D. Smith Janitor F01 09 03 80 Jack W. Vinson Janitor F01 09 03 80 Barbara L. Weigart Janitor F01 09 03 80 Randall L. Keeton Janitor FOl 09 04 80 Dennis M. Castell Janitor F01 09 05 80 Wayne E. Guthrie Janitor F01 09 05 80 M. Neil Haraway Janitor F01 09 05 80 Kenneth D. Sylvester Janitor FOl 09 05 80 Gary R. Cobb Janitor F01 09 08 80

32 Se tember 1980 Personnel Chan es Annual Name Title Effective Date Russell B. Huffman Janitor F01 09 08 80 Willie M. Jenkins Janitor F01 09 08 80 Robert L..Rice Janitor F01 09 08 80 Nicholas L. Austin Janitor F01 09 09 80 Thomas I. Vines Janitor FOl 09 09 80 Robert C. Murphy Janitor F01 09 10 80 Charles Crawley Janitor F01 09 11 80 James R. Hine Janitor FOl 09 15 80 Harlon L. Ramsey Janitor F01 09 17 80 B. Reclassifications Effective Name Former Title New Title Date Rickey E. Holtzclaw SGPO 4th Pd Asst Unit Op 07 23 79 James C. Hall SGPO 4t}1 Pd Asst Unit Op 10 01 79 Danny L. Tuggle Inst Mech AP3 Inst Mech AP4 06 23 80 Wendell K. Holt Elect APlA Elect AP1B 07 21 80 Kenneth W. Brown Elect APlA Elect AP1B 08 04 80 Timothy D. Lane Inst Mech AP3 Inst Mech AP4 08 04 80 Linda G. Murphy Elect APlA Elect AP1B 08 04 80

33 Se tember 1980 Personnel Chan es Annual B. Reclassifications (Continued)

Effective Name Former Title New Title Date Elizabeth L. White Elect AP1A Elect AP1B 08 11 80 Kenneth E. Davis Elect AP1A Elect AP1B 08 18 80 Tony D. Hill Elect AP1A Elect APlB 08 18 80 Patricia F. Roland Inst Mech AP3 Inst Mech AP4 08 18 80 Lona C. Belue Clerk B03 Word Processor B04 08 24 80 Roger D. Shireman Radiochem Lab Radiochem Lab 08 24 80 Anal E04 Anal E05 James A. Green Asst Shft Engr M03 Sup, Janitorial 08 31 80 Servs M03 Robert E. Stone, Jr. Inst Mech AP3 Inst Mech AP4 09 01 80 James S. Watson Elect (H) Elect 09 01 80 Thomas M. Thompson Elect (H) Elect 09 03 80 Lardell Goodloe, Elect (H) Elect 09 04 80 Dan C. Barger Janitor FOl Janitor F02 09 07 80 Martha C. Barnett Janitor F01 Janitor F02 09 07 80 Nellarene P. Cobb Janitor F01 Janitor F02 09 07 80 Larry W. Cole Janitor F01 Janitor F02 09 07 80 Leonard A. Cole Janitor FOl Janitor F02 09 07 80 Michael W. Davis Clerk B02 Clerk B03 09 07 80 Helen J. Franklin Janitor F01 Janitor F02 09 07 80 William C. Freeman Janitor F01 Janitor F02 09 07 80

34 Se tember 1980 Personnel Chan es Annual B. Reclassifications (Continued)

Effective Name Former Title New Title Date James O. George Janitor F01 Janitor F02 09 07 80 Bobby F. Grizzard Janitor F02 Janitor F03 09 07 80 David S. Haney Janitor F01 Janitor F02 09 07 80 Robert L. Ingram Janitor F02 Janitor F03 09 07 80 Martin Johnson Janitor F01 Janitor F02 09 07 80 John W. Maynor, Jr. Janitor F01 Janitor F02 09 07 80 Morris W. Morell Janitor F01 Janitor F02 09 07 80 William L. Sandy Janitor F01 Janitor F02 09 07 80 Burl D. Stark Janitor F02 Janitor F03 09 07 80 E. Jane Wilkerson Janitor FOl Janitor F02 09 07 80 Thomas L. Williamson Janitor FOl Janitor F02 09 07 80 Robert E. Woods Janitor FOl Janitor F02 09 07 80 Garfield J. Taylor, Jr. Sr Inst Mech Sr Inst Mech Fmn 09 08 80 Inez H. Bedingfield Janitor F01 Janitor F02 09 21 80 Austin L.,Burnette Shft Engr H04 Asst Pr Plt Op 09 21 80 Sup M04 David T. Davis Inst Mech AP3 Inst Mech AP4 09 21 80 Herbert L. Johnson Qual Assurance Engr D02 Qual Assurance 09 21 80 Engr D03 Donell King Janitor F01 Janitor F02 09 21 80 Richard W. Shultz Inst Mech AP3 Inst Mech AP4 09 21 80 Ardie R. Champion Unit Op RL Asst Shft Engr M03 09 29 80 James C. Coz Unit Op RL Asst Shft Engr M03 09 29 80 .

Willard B. Dawes, Jr. Asst Unit Op Unit Op 09 29 80

35 Se tember 1980 Personnel Chan es Annual B. Reclassifications (Continued)

Effective Name Former Title New Title Date Johnny E. Duke Asst Unit Op Unit Op 09 29 80 Russell R. Eades Asst Unit Op Unit Op 09 29 80 Charles B. Fisher Asst Unit Op Unit Op 09 29 80 Steve R. Gray Asst Unit Op Unit Op 09 29 80 Charles G. McClain Unit Op RL Asst Shft Engr M03 09 29 80 Marvin L. Meek Unit Op RL Asst Shft Engr H03 09 29 80 Michael V. Hiller Unit Op RL Asst Shft Engr M03 09 29 80 C. Transfers Out Former New Place Effective Name Title Title TQ Date Jeannette Y. Johnson Clk B02 Clk B02 OCH&S 09 07 80 James L. Turner Radiochem Lab Chemist-D01 Trng Ctr 09 21 80 Anal E04 D. Transfers In Former New Place Effective Name Title Title From Date George N. Veal Shmtl Qcr Shmtl Wkr W Creek 08 25 80 David E. Newton Elect Elect Service 09 02 80 Shops Michael N. Brown Radchm Lab Ana Radchm Lab Ana Trng Ctr 09 21 80 Tr E03 Tr E03 James tJ. Burton III Chem Engr D02 Chem 'Engr D03 Ctl & Test 09 21 80 B. Joan Chandler Clk B02 Data Engry Op P&Svs 09 21 80 B02

36 Se tember 1980 Personnel Chan es Annual D. Transfers In (Continued)

Former New Place Effective Name Title Title From Date Edward J. Frederick Radchm Lab Ana Radchm Lab Ana Trng Ctr 09 21 80 Tr E03 Tr E03 Aaron J. Goode Radchm Lab Ana Radchm Lab Ana Trng Ctr 09 21 80 Tr E03 Tr E03 Albert M. Reynolds Radchm Lab Ana Radchm Lab Ana Trng Ctr 09 21 80 Tr E03 Tr E03 E. Return From LWOP Name Title Effective Date Brian E. Williams Engg Coop Student E03 (M) 09 02 80 William B. Pendergrass Engg Coop Student E02 (C) 09 08 80 Theresa M. Pickney Engg Coop Student E04 (C) 09 08 80 F. Placed On LWOP Name Title Effective Date David A. Robeson Engg Coop Student E02 (C) 09 08 80 G. Terminations Name Title Effective Date Fred Fraser Janitor F02 09 02 80 Betty J. Grimes Janitor F01 09 09 80 Harlon L. Ramsey Janitor F01 09 10 80 Randall C. Arnold Elect 09 15 80 John D. Quigley Elect 09 15 80 Joe E. Rice Unit Op RL 09 19 80

37 Se tember 1980 Personnel Chan es Houri Name Title Effective Date J. R. Daniel Mach 09 02 80 Robert W. Daniels Mach 09 02 80 Jimmy D. Dean Mach 09 02 80 Jimmy W. Embry Stftr 09 02 80 Billy J. Emmons Stftr 09 02 80 William E. Griggs Mach 09 02 80 Harry F. Hacker Mach 09 02 80 Bennie D. Stults Mach 09 02 80 Thomas M. Thompson Elect 09 02 80 Harold F. Wilson Stftr 09 02 80 Willie T. Eggleston Stftr 09 03 80 Jack D. Gaston Stftr 09 03 80 Lardell Goodloe Elect 09 03 80 Charles W. Warhurst Mach 09 03 80 Bill C. Thornton Stftr 09 04 80 Edwin R. Warren Mach 09 04 80 Morris G. Brown Cons Lbr 09 05 80 Earnest E. Cosby Cons Lbr 09 05 80 William H. Draper Cons Lbr 09 05 80 James P. Fields Cons Lbr 09 05 80 Leon Pope Cons Lbr 09 05 80

38 Se tember 1980 Personnel Chan es Houri e

Name Title Effective Date Thomas F. Schemeltz Cons Lbr 09 05 80 James J. Smothermon Cons Lbr 09 05 80 Loyd C. Canon Cons Lbr 09 08 80 James J. Cashion Cons Lbr 09 08 80 Jimmie 0. Garrett Cons Lbr 09 08 80 A. D. Jackson Cons Lbr 09 09 80 Kenneth R. Smith Mach 09 15 80 Esadore Meeks Cr Op 09 17 80 Albert S. Smith Mortar Mixer 09 30 80 B. Reclassifications Former New Name Title Title Effective Date James S. Watson Elect Elect (A) 09 01 80 Thomas M. Thompson Elect Elect (A) 09 03 80 Lardell Goodloe Elect Elect (A) 09 04 80 C. Transfers Out None D. Transfers En None

16 0 erations Summar (Continued)

September 1980 Chan e in Procedure There were 54 revisions to plant instructions during the month. 47 instructions were changed primarily for corrections. The remaining 7 revisions related to the safe operation of the plant.

Chan e in Facilit Desi n All changes in facility design will be included in the unit outage summary report.

0 erations Summar (Continued)

September 1980 Surveillance Testin Unit 1 A total of 478 surveillance tests were completed on Unit 1 per 151 different test instructions.

Unit 2 A total of 205 surveillance tests were completed on Unit 2 per 95 different test instructions.

Unit 3 A total of 328 surveillance tests were completed on Unit 3 per 115 different test instructions.

39 Se tember 1980 Personnel Chan es Houri E. Terminations Name Title Effective Date Leslie L. Abernathy Cons Lbr 07 15 80 Gary D. Nichols Hach 08 27 80 Charlie E. Keener Cons Lbr 09 04 80 Lloyd W. Guthrie Carpenter 09 16 80 Johnny Norton Mortar Mixer 09 22 80 Harty F. Hacker Hach 09 29 80

40 Si nificant 0 erational Events Unit 1 Date Time Event 9/01/80 0001 Reactor thermal power. at >99%, steady state control rod sequence "A".

1341 Reactor Scram No. 135 from >99% on turbine stop valves closure, due to water causing a short in pressure relay 62-C1, which caused relay KT 303 to trip turbine.

1736 Commenced rod withdrawal.

2025 Reactor Critical No. 156.

2230 Rolled T/G.

2343 Synchronized generator, commenced power ascension.

9/02/80 1500 Commenced PCIOHR from 82% thermal power.

9/03/80 0040 Reactor thermal power at 95%, holding due to "C" string high pressure heaters isolation due to relief valve flange leak.

1939 "C" string high pressure heaters maintenance completed and heaters placed in service.

2030 Resumed PICOHR from 95% thermal power.

9/05/80 1500 Reactor thermal power at 99%, maximum flow.

9/07/80 0015 Reduced thermal power from 99% to 85% for turbine C. V.

tests and SI's.

0230 Turbine C. V. tests and SI's completed, commenced power ascension.

0705 Commenced PCIOHR from 95% thermal power.

0905 Reactor thermal power at >99%, steady state.

9/10/80 1500 Reactor thermal power at >99%, steady state.

9/12/80 2100 Reduced thermal power from >99% to 50% for control rod sequence exchange from "A" to "B".

9/13/80 0205 Control rod sequence exchange from "A" to "B" completed, commenced power ascension.

2130 Commenced PCIOHR from 82% thermal power.

9/14/80 2300 Reactor thermal power was >99%, steady state.

9/16/80 "1843 Reduced thermal power from >99% to 90% for removal of "A" circulating water pump to allow stop log lA1 to be lifted.

1905 "A" circulating water pump placed in service, (mode to cooling towers would not operate due to stuck gate),

commenced power ascension.

2030 Commenced PCIOHR from 95% thermal power.

2300 Reactor thermal power at >99%, steady state.

41 Si nificant 0 erational Events Unit 1 Date Tillle Event 9/19/80 2230 Reduced thermal power from >99% to 77% for removal of "B" reactor feedwater pump for maintenance (excessive vibration).

9/20/80 0216 Reduced thermal power from 77% to 70% for turbine C. V. tests and SI's.

0315 Turbine C. V. tests and SI's completed, commenced power ascension.

1220 Reduced thermal power from 77% to 50% due to loss of unit preferred power, when shutdown board power supply was trans-ferred.

1225 Commenced power ascension.

2030 Commenced PCIOIR from 80% thermal power.

9/21/80 1550 Reactor thermal power at >99%, steady'state.

9/24/80 2222 Reactor Scram No. 136 (1) from >99% thermal power on load re-ject trip from negative ground on main transformer sudden pressure relay circuit.

9/25/80 0530 Commenced rod withdrawal.

0820 Reactor Critical No. 157, sequence "B".

1038 Rolled T/G.

1107 Synchronized generator, commenced power ascension.

2110 Commenced PCIOIK from 67% thermal power.

9/27/80 0015 Reduced thermal power from 99% to 85% for turbine C. V.

tests and SI's.

0125 Turbine C. V. tests and SI's completed, commenced PCIOMR.

1500 Reactor thermal power at >99%, steady state.

9/28/80 1500 Reactor thermal power at >99%, steady state.

9/29/80 0115 Reduced thermal power from >99% to 85% for backwash and precoat condensate demineralizers.

9/30/80 2400 Reactor thermal power at 85%, holding for condensate de-mineralizer problems.

42 Si nificant 0 erational Events Unit 2 Date Time Event 9/01/80 0001 Reactor thermal power at 92%, EOC-3 coastdown control rod sequence "B" .

1500 Reactor thermal power at 90%, EOC-3 coastdown.

9/04/80 1500 Reactor thermal power at 89%, EOC-3 coastdown.

9/05/80 2130 Commenced reducing thermal power from 89% for refuel shut-down (EOC-3).

2247 Reactor Scram No. 109 (manual) from 35% thermal power to accommodate refueling outage.

9/12/80 1320 Received permission for fuel movement operation, holding due to communication porblems.

1650 Communications restored, commenced fuel movement operation to accommodate LPRM maintenance.

9/19/80 1000 Commenced core fuel shuffle operations.

9/30/80 2400 Refueling operation in progress.

43 Si nificant 0 erational Events Unit 3 Date Time Event 9/01/80 0001 Reactor thermal power at >99%, steady state control rod sequence "A".

1455 Reduced thermal power from >99% to 63% due to "A" recir-culation pump trip from a spurious trip.

1522 Reduced thermal power from 63% to 54% due to "A" recircu-lation pump being out-of-service.

2055 "A" recirculation pump maintenance completed and pump placed in service, commenced power ascension.

2200 Commenced PCIOMR from 75% thermal power.

9/03/80 1500 Reactor thermal power at >99%, steady state.

9/07/80 0230 Reduced thermal power from 99% to 75% for turbine C. V.

tests and SI's.

0330 Reduced thermal power from 75% to 67% due to MSIV-1-26 closing too fast (~1.3 seconds).

0430 Turbine C. V. tests and SI's completed, holding at 67%

due to MSIV 1-26 being left in closed position, awaiting maintenance.

1500 Increased reactor thermal power from 67% to 75%, holding due to closure of MSIV 1-26.

9/10/80 1500 Reactor thermal power at 75%, holding due to MSIV 1-26 being closed.

9/12/80 2245 Commenced reducing thermal power from 75% for shutdown for MSIV 1-26 mainte~y~ce.

2355 Reactor Scram No. 88 (manual) from 35% thermal power to accommodate maintenance to MSIV 1-26.

9/14/80 0525 Maintenance to MSIV 1-26 completed, commenced rod with-drawal.

1009 Reactor Critical No. 98.

1706 Reactor was made subcritical due to a feedwater valve (3-219A) leak.

2233 Repairs to feedwater valve 3-219A completed, commenced rod withdrawal.

2243 Reactor Critical No. 99.

9/15/80 0155 Rolled T/G.

0233 Synchronized generator, commenced power ascension.

1600 Commenced PCIOMR from 76% thermal power.

44 Si nificant 0 erational Events Unit 3 Date Time Event 9/16/80 2330 Reactor thermal power at 92%, maximum flow, awaiting rod,pattern adjustment load drop.

9/17/80 2300 Reactor thermal power at 91%, maximum flow, awaiting rod pattern adjustment load drop, 9/18/80 0700 Reactor thermal power at 90%, maximum flow.

9/20/80 1358 Reactor Scram No. 89 (1) from 90% thermal power, on loss of preferred power when "A" 480 volt shutdown board failed to transfer back to normal causing loss of "A" RPS MG set.

2230 Commenced rod withdrawal.

9/21/80 0104 Reactor Critical No. 100.

0440 Rolled T/G.

0500 Synchronized generator, commenced power ascension.

1500 Commenced PCIOMR from 67% thermal power.

9/22/80 2240 Reactor thermal power at 90%, maximum flow.

9/23/80 2145 Reduced thermal power from 90% to 75% for control rod pattern adjustment.

2255 Control rod pattern adjustment'ompleted, commenced power ascension.

2300 Commenced PCIOMR from 82% thermal power.

9/24/80 0725 Reactor thermal power at 93%, holding due to computer malfunction.

2130 Computer back in service, resumed PCIOMR from 93%

thermal power.

9/25/80 0200 Reactor thermal power at 99%, maximum flow.

1500 Reactor thermal power at 98%, maximum flow.

9/27/80 0130 Reduced thermal power from 98% to 80% for turbine C. V.

Tests and SI's.

0217 Turbine C.V. tests and SI's completed, commenced power ascension.

0300 Commenced PCIOMR from 90% thermal power.

1200 Reactor thermal power at >99%, steady state.

9/30/80 2400 Reactor thermal power at >99%, steady state.

(1) Equipment Malfunction

45 Plant Instruction Revisions September 1980 Cate or Instruction Reason for Re uest Change in EHI-46 To include heat tapes at Facility Freeze Protection Program cooling tower.

Design SI 4.2.A.6 Junction boxes have been Primary Containment and added for test purposes.

Reactor Building Isolation Instrumentation Low Pressure Main Steam Line SIHI-3 Density compensation removed System Instrument Maintenance per ECN P-0130, DCR 1533, Index 3- Instruction Reactor workplan 9870 for Unit 2 only.

Feedwater System SIMI-46 Pressure compensation removed System Instrument Maintenance per ECN P-0129, DCR 1532, Index 46 Instruction Feedwater workplan 9838 for Unit 2 only.

Control System Change EMI-44 To implement DPH N 80 Ml, which Required to Reactor Protection System requires an inspection of the Improve the Scram Solenoid Relays movable contacts for a possible Safety of binding problem.

Operation EMI-80 Recurrence control for LER Maintenance of Inboard and Outboard Drywell Leak Detection Isolation Valves 50-259/8040.'TI-23A When controlling in "A" water Refueling Test Instruction level sensor element in case 23A, Feedwater System of 250 VDC normal supply failure.

46 Re ortable Occurrences Occurrence BFRO Date Descri tion Unit 1 50-259/8060 8/14/80 While performing SI 4.2.B-60, thermostat TS-64-73 for "B" core spray pump area cooler fan was found set above the technical specification limit.

50-259/8061 8/14/80 While performing SI 4.2.B-57, a thermal overload on the breaker for 1A RHR area cooler fan was found tripped.

50-259/8063 8/20/80 While performing SI 4.8.B.4.2, CAM 1-RM-90-251 for the turbine building vent was removed from service for a period exceeding one hour.

50-259/8064 8/20/80 While performing SI 4.8.B.4.2, CAM 1-RM-90-249 for the turbine building roof vents was removed from service for a period exceeding one hour.

50-259/8065 8/28/80 Wind direction at elevation 887 M.S.I.

failed. The LCO to restore the inoperable channel to operating status within 7 days was exceeded.

50-259/8066 9/02/80 Operations personnel observed an annunciation on the torus hydrogen containment atmospheric monitoring.

50-'259/8068 9/01/80 Inspection of the fire protection system by a qualified fire consultant was not per-formed within the 3 year interval as required by Technical Specification 3.11.E.2.

50-259/8069 9/02/80 While performing SI 4.2.A-17, channel B of "refueling zone isolation static pressure permissive and static pressure logic systems units 1, 2, and 3" modulating damper 0-PDC 64-8 failed to close.

50-259/8070 9/19/80 During a review of Unit 1 core verification video tape bundle TY 582 at core location 11-06 was found to be 90'ut of proper orientation.

47 Re ortable Occurrences Occurrence BFRO Date Descri tion Unit 2 50-260/8033 8/15/80 During routine test TI-36A an indicated leak was found on RHR heat exchanger 2B.

50-260/8034 8/15/80 During a routine test TI-36A RHR heat exchanger 2C was found leaking.

50-260/8035 8/30/80 Test personnel detected an increase in pressure on the shell side of RHR heat exchanger 2D while performing TI-36A, RHR heat exchanger leak test.

50-260/8036 8/29/80 During normal operation while performing SI 4.7.H, the H H-76-39 hydrogen monitor for the drywell would not calibrate.

50-260/8037 9/14/80 Fuel assemblies TZ 758 in core location 15-26 and TX 399 in core location 29-28 were found to be rotated 90'rom their correct orientation.

50-260/8038 9/11/80 With the unit in cold shutdown during a scheduled refueling outage, HPCI check valve 2-73-609 failed the local leak rate test.

Unit 3 50-296/8031 8/09/80 During the performance of 1'RI 303 it was found that the EECW flow was below the minimum allowed flow on 3B RHR pump seal heat"exchanger.

50-296/8032 8/25/80 While performing RCIC steam line space high temperature SI 4.2.B-32, lead wires were accidently pulled out of the RCIC speed feedback magnetic pickup connector.

50-296/8033 8/15/80 During routine test TI-36A, a leak on RHR heat exchanger 2B was indicated.

50-296/8034 '/29/80 While investigating overload setting for RHR area cooler fans, the overload for 3A RHR pump area cooler fan was found to be set too high.

When the overload was adjusted to the proper setting, the overload relay failed causing the fan to trip.

50-296/8035 9/Ol/80 . The "A" reactor recirculation pump tripped.

The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> LCO for one pump operation was initiated I,'Technical Specification 3.6.F.1).

48 Re ortable Occurrences Occurrence BFRO Date Descri tion Unit 3 50-296/8036 9/04/80 While running SI 4.9.A.l.a after SEMI-18 had been performed, it was found that diesel generator 3A would not trip to idle speed from a loaded condition.

50-296/8037 9/09/80 During normal operation, while performing SI 4.7.H, H2M-76-39 would not calibrate.

50-296/8038 9/07/80 While running SI 4.7.D.l.b.2 with unit at 99%

steady state power, main steam isolation valve FCV 3-1-26 closed too fast.

Primar Coolant Chemistr September 1980 Parameter Unit 1 Unit 2 Unit 3

1. Gross Radioactivit

a. Crud on 0.45 millipore filter (uCi/ml)

High 3.98E-03 8. 68E-03 5.32E-03 Low 5.00E-04 3.60E-05 4.64E-04 Average 1.22E-03 1.47E-03 1.12E-03

b. Filtrate (uCi/ml)

High 4.01E-01 1.56E-01 2.36E-01 Low 1.13E-01 1.60E-03 6.47E-02 Average 1.79E-Ol 3.29E-02 1.26E-01

2. Sus ended Solids Stained 0.45 milli ore filter ( b High 25 10 Low <10 <10 <10 Average <10 <25 <10

3. Gross Tritium (uCi/ml)

High 1.44E-03 1.17E-03 2.18E-03 Low 1.14E-03 9.88E-04 1.53E-03 Average 1.27E-03 1.04E-03 1.81E-03

4. Iodine-131

~(uC i/ml High 1.02E-03 1.92E-03 7.64E-03 Low 1.89E-04 3.43E-05 2.07E-05 Average 6.88E-04 5.01E-04 1.75E-03 (1) Unit down

50 Primar Coolant Chemistr (Continued)

September 1980 Parameter (Continued) Unit 1 Unit 2 Unit 3

5. Ratio of Todine-131 to iodine-133 High 4.33E-01 1.72E+02 1.32E+01 Low 1.02E-01 3. 45E-01 3.33E-01 Average 2.13E-01 4.93E+Ol 2.64E+00

6. Chloride (ppb)

Limit 100 High <50 <50 Low <50 <50 <50 Average <50 <50 <50 Limit 5.6 or 8.6 High 6.7 6.7 7.0 Low 6.0 5.7 5.8 Average 6.4 6.3 6.2

8. Conductivit (umho/cm 8 25' C.)

eratin Limit 1.0 umho/cm 8 25'.)

Shutdown Limit 10.0 umho/cm 8 25'C.

High 2 8(1) 2 4(l) 2 4(l)

Low .36 .38 .15 Average .72 .81 .53 (1) Unit down

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re 1g, e -Er Eered- it) -LP e'pPs ce len Q -B escaa n eo e-E el: sh EH 20 2 3 4 5 6 7 8 9 10 11 12 13 14 15 . 16 17 18 '19 20 21 22 23 24 25 26 27 28 29 30 31 MONTH O SeP tember 19 80 <<A':5 A'I ONA 0> ~ 0A m<01 ~ 55<5150 lm U,c, 5, 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 6 27 28 29 30 31 <0 1.0 ~0 50 50 0 O H 50 50

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. V. Jg o ed. i.n ce- - amm =T'ld RR eac OV Scr PN -~tO,88. (ma ua7 ue1 pr. GO I dit on 1ng+ US .J.O axi lunl -l'l- eac or s44p m-. =l2 ont ol- r.od pa tel nL omp lte 5.-0 --S rvi I 2 3 4 5 6 7 8 9 10 11 - 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 MONTH OF~Sptkmmer 10 80 ' 63 TVA 7382'PP.l 1 78) NUCLEAR PLANT OPERATING STATISTICS Browns Ferr Nuclear plant Period I lours Month Sen tember 19 80 Item No. Unit No. Average Hourly Gross Load, kW Maximum Hour Net Generation, MWh 3 Core Thermal Energy Gen., GWD(t) 90.660 14.3365 80.1247 Gross Electrical Gen., MIVh 699 320 113 120 625 700 1 438 4 Station Use. MWh 21 477 302 18 Net Electrical Gen., MWh 677 843 107 818 607 023 1 2 4 7 Station Use. Percent 3.07 4.69 2. 8 8 Accum. Core Exposure MWD/Ton 12 610 16 028 1 27 42 9 CTEG This Month, 10 6TU 7,425,276 1 170 328 6 570 852 15 166 456 10 Hours Reactor Was Critical 703.30 118.78 669.05 14 1.13 Unit Use, Hours.Min. 697:13 118:47 654:20 1 470:2 12 Capacit Factor. Percent 88.4 14.3 79.1 60". 6 13 Turbine Avail. Factor, Percent 99. 5 19. 0 100 72. 8 Generator Avail. Factor. Percent 100 19.0 100 Turbocen. Avail. Factor. Percent 99.5 19.0 100 16 Reactor Avail. Factor, Percent 100 16. 5 100 72. 2 17 Unit Avail. F ctor, Percent 98.5 16.5 4.0 18 Turbine Startups 0 19 Peactor Cold Startups 0 0 0 20 21 Gross Heat Rate, Btu/kWh 10,620 10 350 10 500 10 550 22 Net Heat Rate, Btu/kWh 10,950 10,850 10 820 10 890 Cl lJ 23 24 25 26 Throttle Pressure, psig 950 913 38 27 Throttle Temperature, F 539 534 28 Exhaust Pressure, InH Abs. 3.12 3.33 29 Intake Water Temp., F 82.9 87.0 83.8 30 31 32 33 Reactor Feedwater, M Ib/hr 12.4 11.8 11.7 12e 34 Makeup, Percent 36 37 Full Pr. Days to End of Cycle (E) (3) 192 31 38 Oil Fired for Generation, Gallons 2 39 Oil Heatin Value. Btu/Gal. 137 60 40 Diesel Generation, MWh 29.4 Max. Hour I'let Gen. Max. Day Net Gen. Load MWh Time Date MWh Date Factor, % 43 2,972 0600 9-5-80 72, 284 9-4-80 65. 1 Pemarks 1 ~ Informa tion unavailable.

2. Unit 2 refuel outage (EOC-3) began at 2247 hours0.026 days <br />0.624 hours <br />0.00372 weeks <br />8.549835e-4 months <br /> on 9-5-80.

Based on 5% capacity tactor. D t 5 bmitted Date Revised Plant Superintendent TVA 4'C Irn-3 1st UNIT OUTAGE AND AVAILABILITY Brouns Parr Nuclear Plant l licensed Aeactor Power 3293 MIVRh) Unit No. 1152 MW(e) MonthiYear Septcnber 1980 Generator Rata)g Design Gross Electrical Rating 1098 4 MW Period Hours Vail METHOD OF UN I T CORRECTIVE ACTION T)dne Vn)l Available Time NOt Ava))able SHUTTING STATUS Time T)me OUTAGE CAUSE TAKEN TO PAEVENT Vn) I O)dt In DOsvN DURING REPETITION Total Nol V)ed Tw bine Reactor REACTOR OUTAGE sids radn )S)S rdbn ~lr) s Mn Nds M)n H)$ Mdn I srs Min lbs M)n I id) Mdn ~58 06 07 ~0) 55 03 r 55 13 41 23 43 Turbine trl due to sto Scrub liat Standby 24 00 5 IO 12 13 15 18 P.t S~ "4 22 22 00 24 100 22 t22 0~138 22l 22 ~l,d

• d Scran Oot Standby

~tt on natn transforner sudden 25 J 8~0 L22 )3 ~01 37 05 130 07 ~r) ~41 ressure rota 27 29 30 gC 0 31 1 'tat 1~08 57 )79 13 11 44 03 I 55 11 03 >C OC t, UNIT OUTAGE ANO AVAILABILITY Nuclear Plant Licensed Reactor Power 3293 MW(lh) Urut No Generator Rating~252 MW(e) Month/Year Se cenbee 1980 Design Gross Oectricat Rating~~84 Mw Period Hours 720 Vnil METIIOO OF UNIT CORALCTIVE AC1ION time Vml Avaelbre Time eeet AVasrabre Time Time SIIUTTING STATUS TAI<EN 10 PREVENT OUTAGE CAUSE 1 nrar ~ Cen. llOl Vied Tw bine Aeactor Vml Ovt In DOWN DURING ACPLT ITION nay I lis 4'I n I lis l.bn lbs rvbn ~lus. Msn lbl Mm ~S4S ItlIn l 4S Msn lb s Min llis Mm REACTOR OUTAGE I 24 I 00 24 00 2 ~24 00 ~24 00 22 I 47 22 lC7 06 54 06 i 54 0LLL3 24 '00 &1~ 24L 00 24 00 24 00 I 12 13 15 22 I I I I 25 2Ci I I 27 29 drs ~24 L" Intel 118 47 18 47 582 I 54 82 54 ~ 'is i Licensed Rcatlnr Power 3293 Gcncialnr Rating 1152 Design Gioss Electrical Rating I.IW(c) hIW(th) 1090 ~ 4 MSV U is N .~ UNIT OUTAGE ANO AVAILABILITY Srovns Petr Nuclear Plant hlonih/Year Period Hours Se 720 tenbec 19SO Vnsl Tinsc Unit AvaiNbte Time Not Available METHOD OF UNIT CORRECTIVE ACTION Time Time SHUT TING STATUS TAKEN TO PREVENT OUTAGE CAUSE Toter Gcn, Nol Vscii Tsss bine Reactor Vnil Ovl In DOWN DURING REPETITION trst Mn t ris c.lsn Cist htsn ~trit lain leS Min ~its r Min ~His Mso lrsr htin tlii Min REACTOR OUTAGE 24 i00 24 00 c c sJ IO II 24 IOO 24 ~00 12 00 l05 ~23 55 Maintenance to MSIY 1-26 and Manual llot Stan b 13 c 24 00 feedvater valve 3-219A I ~4 13~08 l5 2it I00 21.IQL 02 33 )fi l7 18 lg +4 I 0 0 jk I 0 08 I32 13 5S lass of nAn RPS MG Sct Stean Ilot Standb ?I ?7 2'K I28 24 1'9i 00 ~05 00 00 05 00 ~7 I ?l c ?6 27 29 t c 30 2~4 24 00 I 3l I Trit.tt 676 31 654 20 22 11 43 9 67 OUTAGE

SUMMARY

September 1980 The unit two reactor shutdown sequence was conducted in an orderly process on September 5, 1980, for refueling activities and routine maintenance to plant equipment. The refuel activities involve disassembly of Unit 2 reactor for refueling operation with reactor startup scheduled for October 26, 1980.

The routine maintenance involves inspection and repairs to major components and safety systems within the plant. The initial containment entry was conducted at 1:05 P.H. on September 6, 1980.

The planned duration for the Unit 2 cylce 3 refuel outage is 49 days. The pre-planned schedule shows that turbine inspection and maintenance work sequence as the critical work path, a fix'st at Browns Ferry Nuclear Plant. In order to prevent the outage duration from exceeding the 49 day schedule, non-curcial modifications are being minimized, however, major modifications intended to meet safety requirements are being performed.

68 ELECTRICAL MAINTENANCE

SUMMARY

September 1980 Unit 1 There were no major maintenance on CSSC or non-CSSC equipment during the month. Unit 1 tripped when a ground in the wiring to the sudden

~

pressure relay caused a transformer trip. The ground was cleared and the unit returned to service. A summary of non-CSSC and CSSC maintenance activities is given in the following electrical maintenance summary.

Unit 2 Major activities include major maintenance inspections to PCB's 5244 and 5248, inspection of 2A 500 kV transfoxmer, and inspection and repair of leaks on 2B and 2C main transformers. At the close of the month, work is 90% complete on PCB 5248 and 25% complete on PCB 5244. The inspection of 2A main transformer is complete and final testing in progress. Work continues on 2B main transformer. The 2B condenser circulating water pump motor failed on September 2. After testing, the motor was sent to the service shop for repairs. The motor is due back in early October.

Routine refueling outage activities are in progress. A summary of other non-CSSC and CSSC maintenance activities are given in the following elec-trical maintenance summary.

Unit 3 A scram occurred on Unit 3 when returning 480 volt shutdown board 3A to service following changing the tap setting on transformer TS3A. The tap setting was also changed on transformer TS3B and TS3E. There was no

69 ELECTRICAL MAINTENANCE

SUMMARY

(Continued)

September 1980 Unit 3 (Continued) major maintenance on CSSC and non-CSSC equipment. A summary of other non-CSSC and CSSC maintenance act'ivities is given in the following elec-trical maintenance summary.

Common NONE

DROWNS PEit1;YiilUCLHtll PLAIT UHIT 1 ELECTRICAL HAINTENANCE SRBfhRY 1'or the Honth of E ect on Sa c Action Taken 0,". te System Component Nature of Operation of Cause of Results of To Preclude Haintenance The Reactor Halfunction Halfunction Recurrence 9/2/8 Neutron RBH Bypass RBH Bypass NONE RBH Switch Bad Switch would not go Replaced RBH switch.

Honitor in Switch Switch on in bypass Checked switch for panel 9-5 proper operation.

needs repair- Switch functioned ing okay. TR8 179518 9/23/80 RNR ECV-74-71 RHR valve Unit in limiting Hotor burned up Valve inoperable. Performed EHI 71.

1.-74-71 won' condition for Replaced old motor.

run operation Performed EHI 18.

(TS.3.5.8.7) Valve now functioning properly. TR8 165755 LER No. BPRO 50-259/

8072 o

URU!'UR "URRT UUCUElS PXRUT UUXT 2 IQ,XNTENANCE SUtkfARY For the Honth of September ]9 80 E ectonSae Action Taken Nature of Operation of Cause of Results of To Preclude D.". te System Component ftmc tion Recurrence Haintenance The Reactor Halfunction ~Rfal 2B i 9/21/80 RBCCH RBCCH Pump 2B RBCCH pump NONE tutor failed. Loss of 2B RBCCH Hotor repaired motor trips pump motor. shop, then at'ervice out. Sparks returned to service.

reported com- TlU/ 178647, 160689 ing from the motor.

9/22/80 RHR FCV-74-24 Valve will NONE Hire loose in alve would not cycle Tightened loose wire not cycle . motor starter> on overload assembly overload assembly in motor starter.

Valve operated okay. TRt 1'78632

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URONNS PERRY NUCLEAR PLRNT UNIT ELECTRICAL MAINTENANCE

SUMMARY

NON-CSSC E UIPMENT Pot tbe Noetb oP SePtelnber IP SO Nature of Cause of Malfunction or onent Maintenance Maintenance Action Corrective Action DaLe System Com 9/13@0 RWCU 2A RMCU 2A RWCU demin. F Step switch not working Adjusted step switch. Checked demin. valve will not properly. okay. TR8 169260 open during precoat step.

9/17/80 Reactor water 2B reactor 2B RMCU pump Motor bad. Replaced with rebuilt motor.

cleanup. water clean- 'motor locked up Checked okay, Tlg 180452 up.pump motor 9/19/80 Main steam FCV-1-59 Valve will not Motor burned up and Replaced motor an'd torque switch.

operate. torque switch bad. Performed EMI 18. Checked okay,

-

TR8 160644 9/21/80 FCV-69-8 RMCU demin, bypass Broken limit switches in Replaced broken limit switches.

valve will only, valve FCV-2-69-8. Performed EMI 16 and 18. Checked open and close. okay. T1UI 169299

UROIINS PERRY NUCLEAR PLAN'1'NLT NON-CSSC E UZPlmNT ELK'CTRXCAL ifAXHTENANCH SUiQlARY pot tha Hooth of RapteaIbet 19 80 Nature of Cause of Halfunction or l)a te System Com onent Haintenance Haintenance hction Corrective Action 1

9/25/80 RWCU 3A RMCU 3A RMCU demin. Switch .contacts dirty. - "

Inspeated switches and cleaned demin. stepping switch contacts. Checked okay. Tip stepping needs to be 179.318 switch cleaned and checked.

76 MECHANICAL MAINTENANCE SALARY September 1980 Unit 1 On September 19, 1980, the 1B RFP was experiencing high vibration problems. The RFP coupling was inspected and was found to be low in lub-ricant. The RFP coupling was disassembled, cleaned, and filled with new lubricant. This corrected the vibration problem. The mechanical controls on all RFP turbines were inspected for proper lubrication and cleanliness.

Unit 2 Twenty-three of the CRD scram pilot solonoid valves were rebuilt during the month. A number of valves throughout the turbine and reactor building were worked on for packing leaks, broken diaphragms and o-rings.

Some of the small hand control valves were replaced due to steam cuts around bonnet gasket surfaces. The 2A RCW booster pump discharge check valve was replaced because the old discharge check valve was stuck in the open position and beyond repair. The 2B reactor water cleanup demineralizer resin trap was replaced on 'September 6, 1980. 2A RCW pump isolation valves were dis-assemble, cleaned and reassembled. The RCIC turbine and pump were inspected during the last week of September and all outage work was completed September 30, 1980. The Unit 2 HPCI work is behind schedule due to delayed shipment of the new pedestal. The disassembly work has begun on the removal of the temporarily repaired pedestal performed earlier this year due to water hammer damage. The RHR and recirculation system valves graffoil packing was adjusted during the month.

77 MECHANICAL MAINTENANCE

SUMMARY

(Continued)

September 1980 Unit'3 Unit 3 ran essentially all month with only minor repair work with the exception of repair work to 3B MSIV. The MSIV had closed too fast during a routine surveillance instruction test. The unit was removed from service September 13, 1980, for inspection and repair to the MSIV.

The valve operator was found to be approximately three quarts low of oil.

Oil was added to the operator and the valve functioned properly. No sign of oil was evident on the floor or around the valve at the initial inspection.

3B CRD filter required replacing on September 25, 1980. The Unit 3 RCIC had to have three quarts of oil added on 'September 8, 1980. The outboard packing on 3A fuel pool cooling pump required tightening on September 22, 1980.

Common Scheduled maintenance of all service air compressors were performed September 24, 1980. No significant problems were found. The raw cooling water. lines to the CRD pump bearing were cleaned during the first part of the month. The 1B RHRSW pump vibration reading was above the acceptable limits on September 25, 1980, and the pump was pulled and disassembled during 'the last few days in September.

2

'I CSSC E UXP:kk;I!T IKCIU.NXCAL HAXNTENAN"F. SUIQ4<RY EFFECT ON SEVE ACZXON TAI'EN DATE SYSTP~I CC~!PONENT NATUIIK OP OE'EBATXO:I OF CAUSE OP RESULTS OF '19 PRECLUDE E'i1.ViTENAi ICE TIIE -RI~CTOR I!.'iLPUNCTXON I'ALFUNCTXON RECURRENCF.

9/22/80 RCTC Turbine exhaus Ruptured none old disk Ruptured disk Replaced disk with rupture disk disk ruptured new one TR 103732

3 CSSC EOUXPH 2!T HECHAKXCAL KXINTENANCE SUGARY EFFECT ON SAFE ACTION TAl:i;N BATE SYSTBf CGiaiPONEN T iB.'L'URE OF OPERATXO:i'F CAUSE OF RESULTS OF '10 PRECLUDE KXXNTENANCE 1dE REACTOR Y~LFUNCTION NALFUNCTXGN RECURRENCE 9/17/80 Fuel pool 3A FPC pump Outboard pack- None Packing leak Packing leak coolin Adjusted packing in TR 178817

1 I.'02-CSSC~EUIPl KHT lKCHANICAI, MLU"HA11CE SLMQRY For the ltoeth of September tp 80 Nature of Cause of 14alfu>>ction or Date S stem Com nnent ?faintenance llaintenance Action Corrective Action 9/12/80 Radwaste FSV-77-19 Bad solenoid valve Bad solenoid valve Replaced solenoid valve TR 182079 9/19/80 Reacotr Feed- 1B RFP High vibration Lube oil dried out in Cleaned coupling and put new oil um cou lin TR 103114

t0:4-CSSC~F. UIPl KHT >?EC?>AHICgZ. HAP?T"HAHCE SEQfAPY For the ?fonth of September 19 80 Nature of Cause of Malfunction or Date S stem Com onent  ? fai.n tenance llaintenance Action Corrective Action S

9/80 RCW 2A RCM pump Isolation valve Isolation valve out of Removed, cleaned, and a'djusted, and isolation 2-24-516 A,B,&C adjustment reinstalled valves ,2-24-520 A,B,&C TR 119083, 119085, 119086 would not close

.9/28/80 Hain Steam PCV 1-167 Valve binding Valve binding Cleaned, lubricated, and adjusted valve TR 166667 9/24/80 Heater drains LCV-6-73A Bad o-rings and Bad o-rings and diaphragm Replaced o-rings, diaphragm.

and vents diaphragm Adjusted packing and lubricated ste TR 166658 9/25/80 Heater drains LCV-6-73B Bad o-rings and Bad o-rings and diaphragm Replaced o-rings, diaphragm.

and vents diaphragm Adjusted packing and lubricated sten TR 166659 9/25/80 Heater drains LCV-6-62A Bad o-rings and Bad o-rings and diaphragm Replaced o-rings, diaphragm.

and vents diaphragm Adjusted packing and lubricated ste TR 166661 9/25/80 Heater drains LCV-6-62B Bad o-rings and Bad o-rings and diaphragm Replaced o-rings, diaphragm.

and vents diaphragm Adjusted packing and lubricated stem TR 166662 9/10/80 Feedwater HCV-3-211A Bad seat in valve Bad seal in valve Replaced valve TR 180437 9/9/80 Heater drains HCV-6-418A Bad seat in valve Valve seat worn Replaced valve and vents TR 180438

82 INSTRUMENT MAINTENANCE SALARY September 1980 Unit 1 There were no major instrument maintenance or modification activities on Unit 1 this month.

Unit 2 Extensive time and effort has been expended this month on refueling outage related routine calibration, maintenance and modification activities. Major areas include:

Installed the Hays-Republic oxygen and hydrogen analyzer system, including writing of new surveillance instructions, maintenance procedures, and initial calibrations.

Implemented DCR 1937 by work plan 6617. This modification replaces six mercoid pressure switches in the condensate system.

Implemented DCR 1892 by work plant 9818. This modification prevents feed-water control loops from reading downscale upon meter failure.

Replaced twelve LPRM detector assemblies due to end of life criteria. An additional LPRM assembly had to be replaced due to being irreparably damaged during preliminary LPRM activities. All thirteen assemblies are of the GE NA-200 breeder types.

Representatives from the General Electric Company in conjunction with Instrument Maintenance personnel conducted extensive testing on the EHC system to resolve the tubing vibration and servo valvea'ilure problems. Realignment and modifications include: increase the dampening on the fluid pressure sensors, changed the valve movement operating point to the second slope of the Diode Function Generator and attached the sensing line to the wall at four foot intervals.

83 INSTRIRKNT MAINTENANCE

SUMMARY

(Continued)

September 1980 Unit 3 N

There were no major instrumentation maintenance or modification activities on Unit 3 this month.

Common DCR's were initiated this month concerning the following modifications:

-1. Replacement of FE-66-111 in the off-gas system, due to the flow element not being reliable and spare parts not available.

2. Enclose and air condition the off-gas hydrogen analyzer area. This modification will imporve the environment of the electronics and therefore improve the reliability of the system.

3. Incorporate additional HPCI and RCIC testing parameters'into the Real-time evaluation, monitoring and analysis system.

4. Replacement of the freestanding E-Field mounted on the face of pilars at the intake pumping station with a microwave transmitter and receiver system.

5. Extending the E-Field in sectors 4 and 5 along the wingwalls of the intake to the waterline.

6. Installation of additional standby batteries in the PERIM-ALERT and Wells Fargo system to sustain operation for at least 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following a power failure. This modification is due to NRC specification WA-00450B.

INSTR12KNT MAINTENANCE SUKfARY (Continued)

September 1980 Com uter S stem System availability for the units 1 and 2, and unit 3 process computer was 98.47% and 99.86% respectively. Downtime was due to analog scanner problems which was resolved by replacing 25 leaking diodes.

System availability for the PRIME computer was 100% with only routine mainte-nance being performed.

System availabiltiy for the RRRMS PDP 1134 computer was 99.93%. Downtime was due to high temperature in the computer room (1/2 hour).

The Instrument Maintenance section in conjunction with the Controls & Test Section has installed two NOVA 1200 computers in the secondary alarm station to monitor the RUSCO MAC S40. This system will allow report generating and up-to-

'

date cross reference of all coded data form the cardkey system.

Securit S stems RUSCO Card Access S stem On September 2, we experienced another system malfunction due to power transfer. As of this date, we still have not received the recommendations from Chattanooga or Knoxville for an uninterruptable power supply to help stabilize our power source.

CCTV Browns Ferry now has 18 CCTV cameras in operation. These cameras and associated monitors are requiring daily maintenance for adjustment and re-location for security and fuel pool activities.

Intrusion Detection Hells Far o Performed routine maintenance and repair on MP2 modules, AS24 boards, and Cu-3 boards. Failure rates on these components are much higher than expected.

85 INSTRUMENT MAINTENANCE St&MARY The following instrument Maintenance Summary tabulates man-hours expended on instrument maintenance, calibration, loop checks, and work plans for various plant systems.

Unit Total Svs tern 3 M-H Main Steam 30

2. Condensa te Ho 0 39 515 74 62

3. Reactor Feedwater

5. Extraction Steam

6. Heater Drain and Vent 40 320

12. Auziliarv Boiler

18. Fuel Oil

23. RHR Service Water 51 51

24. Raw Coolin Water

25. Raw Service Water

26. High-Pressure Fire Protection

27. Condenser Circulatin Water 36

28. Water Treatment

31. Air Condition Coolin and Heatin 10 10

32. Control Air 21

33. Service Air

34. Vacuum Primin

35. Generator H dro en Coolin

37. Gland Seal Water

39. COo

40. Station Draina e

43. Sam lin and Water Oualitv 45 45 94

44. Buildin Heatin

46. Feedwater Control

47. Turbo enerator Control 21 181 207

53. Demineralizer Backwash Air

56. Temo rature Monitorin 102 71 173

58. Biothermal Research 10 10

63. Standbv Li uid Control Prima ~ Con tainmen t 51 55 28 134

65. Standbv Gas Treatm nt 66 Off-Gas 157 237 468

'7.

Eeer enc E nionen~ttoolin !Pater 12 12 32

68. Reactor Water Recirculation 304 28 340

69. Reactor Water Cleanup 35 147 187

70. Reactor Buildin Closed Coolin Hater 49 55

71. Reactor Core Isolation Coolin

73. Hi~h-Pressure Coolin In ection 43 72 10 125

74. Residual Heat Removal 34

75. Core Sorav Isolation Coolin 32 32

86 INSTRUMENT MAINTENANCE S'CHARY (Continued)

Unit Total S stem M-H

76. Containment Inertin

77. Radvaste 1 0

78. Fuel Pool Coolin and Demineralizin

80. Prima Containment Coolin

82. Standb Diesel Generator

84. Containment Air Dilution

85. Control Rod Drive H draulic

90. Radiation Monitorin 308 550 228 1086

92. Neutron Monitorin Travelin In-Core Probe TIP 26 24 50

96. Recirculation Floe Control

99. Reactor Protection RPIS 330 335 EHC 245 259 SI 743 1075 781 2599 IMI 129 151 504 427 1211 Comouter 4020 313 313 Prime RRK 1S Pere herials 321 321 Card Ke 203 203 intrusion Detection 304 304 Closed Circuit T.V. 256 256 Portal Monitors 49 49 98 Standards 16 319 319 654 Coolin Towers 331 331 General Instrument Pork 443 179 139 761 Instrument Repair 32 32 Recorder Maintenance 223 223 General Employee Trainin 65 177 61 307 ADDrentice Trainin 262 308 204 774 H P. Trainin 12 8 39 B'.JR Instrumentation) Trainin "C" Zone Dressout 100 211 127 438 Radiochem 1ab 260 260 520 H P Lab 255 255 TR's Received/Completed 45 45 96 86 33 27 125 111 299/269 Dual Rate Foremen 62 20 93 Outa e Sup ort 25 Hand and Foot Monitors 47 47 X Rav 17 17 I.D. Camera 42 Overtime Seismic Monitors'2 292 239 30 5003 441 5975 30

BROWS l FERkY'UCLEAR PLANT UNIT 1,2,3 INSTRUI'IENT MAINTENANCE SUI MARY I

CSSC E UIPlfENT FOR THE HONTII OF September 19 80 NATURE EFFECT ON SAFE CAUSE ACTION TAKEN DATE SYSTEH COMPONENT OF OPERATION OF OF RESULTS OF TO PRECLUDE MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE Unit 1 9-2 Containment H 2

A-76-37 Replace None Faulty Heter Alarm would not None Inerting reset P rimary PDT-64-138 Calibrate None Zero 'Shif t Did Not Indicate None Containment with Redundant 9-24 Reactor TI-70-56 Replace None Broken Indicator Did Not Indicate None Building Closed Cool-ing Hater Unit 2 9-23 lligh Press- PS-26-78J Calibrate None Instrument Drift Setpoint Incorrect None ure Fire Protection Unie 3 9-25 Emergency FI-67-9A Calibrate None Zero Shif t Indicated Low Flow None Equipment -12A Cooling Mater RllR Service PT-23-11 Calibrate None Zero Shift Indicated Low Pressur None Hater FH-23-42 Calibrate None Zero Shift Indicated Low Flow None FH-23-48 Calibrate None Zero Shift Indicated Low Flow None

88 Radioactive Li uid Effluents September 1980

1. Gross Radioactivit Units a) Total Release (1) Curies 1.36E+00 b) Average Diluted Concentration Released uCi/ml 3.16E-08 c) Maximum Concentration Released uCi/ml 1.91E-07 d) Percent of Applicable Limit (20 Ci/quarter) 6.80E+00

2. Tritium a) Total Release Curies 1. 93E+00 b) Average Diluted Concentration Released uCi/ml 4.49E-08 c) Percent of Applicable Limit (3E-03 uCi/ml) 1.50E-03

3. Dissolved Noble Gases (2) a) Total Release Curies <3.07E-02 b) Average uCi/ml <7.12E-10 c) Percent of Applicable Limit (6E-06 uCi/ml) <1.19E-02

4. Gross Al ha Radioactivit a) Total Release Curies 3.96E-05 b) Average Diluted Concentration Released uCi/ml 9.19E-13

5. Volume of Li uid Waste to Dischar e Canal Liters 2.87E+06

6. Volume of Dilution Water Liters 4.33E+10

7. Isoto es Released Ci Ba/La-140 <5.15E-04 Co-58 <1.85E-03 (1) Based on pre-release analyses which are not decay corrected (2) includes Xe-133, Xe-135, and others (3) Released on basis of MPC

89 Radioactive Li uid Effluents (Continued)

September 1980 Isoto es Released (Continued) Units Co-60 <1.31E-02 Cr-51 <1.56E-02 Cs-134 <2.64E-02 Cs-137 <3,20E-02 Fe-59 <8.01E-04 I-131 <6.94E-03 Mn-54 <2.58E-03 Mo-Tc-99m <8.39E-04 Na-24 2.71E-02 Nb-95 <1.17E-03 Sr-89 2.98E-03 Sr-90 4.07E-04 Zn-65 <1.51E-02 Zr-95 <1.25E-03 Others F-18 7.94E-04 Cs-136 <9.02E-04 Cu-64 <9.62E-03 I-133 <2.04E-03

90 Radioactive Liquid Effluents (Continued)

September 1980 Others (Continued) Uni ts Ci Mn-56 <1.47E-04 Sb-122 <3.53E-03 Sb-124 <7.03E-04 Xe-133 <1.51E-02 Xe-135 <1.17E-02 I-135 <6.82E-03 Br-82 <1.07E-03 As-76 <3.78E-03 Ag-110m <2.02E-03 Sb-125 <7.39E-04 As-74 <7.39E-04 NOTE: Symbol < indicates sums of nuclide activity influenced by values representing threshold limit of analytical sensitivity. Thus, re-ported values are conservatively higher than actual release.

91 Airborne Releases (1)

September 1980 Summation of All Releases Unit This Month A. Fission and Activation Gases

1. Total Release Ci <1.43E+04

2. Average release rate for period uCi/sec. <4.73E+03

3. Percent of Technical Specification limit 9.46E+00 B. Iodines

1. Total Iodine-131 Ci 7.50E-03

2. Average release rate for period uCi/sec. 2.48E-03

3. Percent of Technical Specification limit 6.21E-01 C. Par ticulates

1. Particulates with half-lives 8 days <3.29E-03

2. Average release rate for period uCi/sec. <1.09E-03

3. Percent of Technical Specification limit 2.7E-01

4. Gross Alpha radioactivity Ci <1.43E-09 D. Tritium

1. Total release Ci 7. 07E+00

2. Average release rate for period uCi/sec. 2.34E+00

3. Percent of Technical Specification limit 1.87E+00

4. Ground Level Release Ci 6.74E+00

5. Elevated Release 3.31E-01 (1) Reporting period 35 days

92 Airborne Releases (Continued)

September 1980 Elevated Releases A. Fission Gases Unit This Ifonth

1. Krypton-85 Ci 7.73E+00

2. Krypton-85m 2.05E+03

3. Krypton-87 <8.19E+02

4. Krypton-88 Ci <3.18E+03

5. Xenon-133 6.28E+03

6. Xenon-135 <1.88E+02

7. Xenon-135m Ci <8.17E+01

8. Xenon-138 Ci <4.60E+02 Others (specify)

9. Argon-41 Ci <3.13E001 Unidentified Ci NA Total for Period Ci <1. 31E+04 B. Iodines

l. Iodine-131 Ci 5.18E-03

2. Iodine-133 <4.45E-03

3. Iodine-135 <3.99E-03 Total for Period <1.36E-02

93 Airborne Releases (Continued)

September 1980 Elevated Releases C. Particulates Unit This Month

l. Strontium-89 Ci 4.61E-06

2. Strontium-90 3.82E-07

3. Cesium-134 <1.03E-05

4. Cesium-137 Ci <1.01E-05

5. Barium-140 <6.55E-05

6. Zirconium-95 Ci <2.19E-05

7. Niobium-95 <9.79E-06

8. Cobalt-58 Ci <1.02E-05

9. Ifanganese-54 <8.85E-06

10. Zinc-65 Ci 3.78E-05

11. Tron-59 <2.25E-05

12. Cobalt-60 1.73E-05 Other (speci fy)

N/A

13. Lanthanum-140 <6.70E-05 Total for Period Ci <2.86E-04 D. Tritium Ci 3.31E-01

94 Airborne Releases (Continued)

September 1980 Ground Level Releases A. Fission Gases Unit This Month

1. Krypton-85 <3.69E-03

2. Krypton-85m <2.78E+01

3. Krypton-87 Ci <6.80E+Ol

4. Krypton-88 <9.11E+01

5. Xenon-133 <1.22E+02

6. Xenon-135 <1.85E+02

7. Xenon-135m <1.86E+02

8. Xenon-138 Ci <4.89E+02 Others (specify)

9. Argon-41 <4.14E+01 Unidentified Total for Period <1.21E+03 B. Iodines

l. Iodine-131 Ci 2.32E-03

2. Iodine-133 <1.79E-03

3. Iodine-135 Ci <9.94E-03 Total for Period <1.41E-02

95 Airborne Releases (Continued)

September 1980 Ground Level Releases C. Particulates Unit This Month

1. Strontium-89 Ci 1.93E-06

2. S trontium-90 1.79E-06

3. Cesium-134 <1.35E-04

4. Cesium-137 Ci 1.30E-04

5. Barium-140 Ci <4.87E-04

6. Zirconium-95 <2.69E-04

7. Niobium-95 <1.21E-04

8. Cobalt-58 <1.18E-04

9. Manganese-54 <1.20E-04

10. Zinc-65 <4.98E-04

11. Iron-59 2.88E-04

12. Cobalt-60 4.32E-04 Others (specify)

N/A

13. Lanthanum-140 Ci <3.94E-04 Total for Period <3.00E-03 D. Tritium 6.74E+00

96 Solid Radioactive Waste (1)

September 1980 Low Level Shi, ments Approximate Volume of Sludge Shipped 42.1 Cu. M. (1486 Cu. Ft.)

Total Curies Shipped 195.2 Principal isotopes MAP, MCP (Dewatered Resins)

Dis osal Facilit 9/08/80 Barnwell, SC 9/10/80 Barnwell, SC 9/12/80 Barnwell, SC 9/16/80 Barnwell, SC 9/18/80 Barnwell, SC 9/21/80 Barnwell, SC 9/23/80 Barnwell, SC 9/30/80 Barnwell, SC Hi h Level Shi ments Approximate Volume of Sludge Shipped 17.7 Cu. M. (624 Cu. Ft.)

Total Curies Shipped 282.6 Principal isotopes MAP, MCP (Dewatered Resins)

Dis osal Facilit 9/09/80 Barnwell, SC 9/15/80 Barnwell, SC 9/19/80 Barnwell, SC 9/24/80 Barnwell, SC Footnotes on next page.

97 Solid Radioactive Waste (Continued)

September 1980 Slud e Inventor Condensate and Waste Phase Separator Sludge on Hand 34.0 CU. M. (1199 CU. Ft.)

Cleanup Phase Separator Sludge on Hand 5.7 Cu. M. ( 200 Cu. Ft.)

Drummed Shi ments (2)

Total Number of Drums 233 Total Curies Shipped 18. 2 Principal Isotopes CR5 1 ~ CS 1 37 ~ ZN65 j C060 ~ MN54 ~ SR90 Date Shi ed Dis osal Facilit 9/17/80 Barnwell, SC 9/19/80 Barnwell, SC

98 Solid Radioactive Waste (Continued)

September 1980 Boxed Shi ments (2)

Total Number of Boxes 22 Total Curies Shipped 0.1 Principal Isotopes CR51,CS137,ZN65,C060,i$ 54,SR90 Dis osal Facilit 9/11/80 Barnwell, SC 9/17/80 Barnwell, SC (1) All shipments by Sole-use truck.

(2) Combination box/drum shipments on these dates.

99 Solid Radioactive Waste (Continued)

September 1980

~scmaac Shipped to Stored Allotted Barnwell Onsite ~sac e Drums 1747.5 ft 1650 ft 6149.5 ft Boxes 2292 ft 3100 ft Resin 2110 6149.5 ft 4750 ft 6149.5 ft

100 Effluent and Waste Dis osal Monthl Re ort September 1980 Su lemental Information

1. Batch Releases Li uid Units a) Number of batch release Each 32 b) Total time period for batch releases Minutes 10883 c) Maximum time period for a batch release Minutes 783 d) Average time period for batch release Minutes 340.1 e) Minimum time period for a batch release Minutes 180

2. Batch Releases Gaseous None

3. Abnormal Releases Liquid None

4. Abnormal Releases Gaseous None

101 Resin Usage for September 1980 Resin Cu. Ft.

Powdered Volume Bead Resins Radwaste Floor Drain Filter 516.0 516.0 Waste Demineralizer 130.0 Waste Filter 192.0 192.0 Fuel Pool Demineralizers (1) 16.0 16.0 Reactor Water Cleanu Unit 1 120.0 120.0 Unit 2 56.0 56.0 Unit 3 12.0 12.0 Condensate Demineralizers U it 1 827.0 827. 0 Unit 2 198.0 198.0 Uni 376.0 376.0 Totals 2313.0 130.0 2313.0 (1) Total Resin Volume includes 16.0 cu. ft. of Overlay Haterial.

(2) Total Resin Volume includes 63.0 cu. ft. of Overlay Haterial.

(3) Total Resin Volume includes 20.0 cu. ft. of Overlay Haterial.

(4) Total Resin Volume includes 17.0 cu. ft. of Overlay Haterial.

102-Powdered Resins  % Total Usa e September 1980 Radwaste Usa e Total Floor Drain Filter 516.0 / 2313.0 22.3 Waste Filter 192.0 / 2313.0 8.3 Reactor Water Cleanu Unit 1 120.0 / 2313.0 5.2 Unit 2 56.0 / 2313.0 2.4 Unit 3 12.0 / 2313.0 0.5 Condensate Demineralizers U it 1 827.0 / 2313.0 35.8 U.it 2 198.0 / 2313.0 8.6 (4)

"'.it 3 376.0 / 2313.0 16.3 Fuel Pool Demineralizers (1)

ALL UNITS 16.0 / 2313.0 0.7 (1) Total Resin Volume includes 16.0 cu. ft. of Overlay Material.

(2) Total Resin Volume includes 63.0 cu.-. ft. of Overlay Material.

(3) Total Resin Volume includes 20.0 cu. ft. of Overlay Material.

(4) Total Resin Volume includes 17.0 cu. ft. of Overlay Material.

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106 Fuel Claddin Inte rit Parameters September 1980 Unit 1 Reactor Water Iodines (uCi/sec.)

Date I-131 I-132 I-133 I-134 I-135 9-04-80 2. 97E+00 1. 68E+01 6.86E+00 3.71E+Ol 1.24E+01 9-22-80 l. 92E+01 3. 15E+02 1.08E+02 3.77E+02 1.82E+02 Fission Gases at Dischar e of SJAE (uCi/sec.)

Date Xe-138 Kr-87 Kr-88 Kr-85m Xe-135 Xe-133 9-02-80 1. 33E+03 4. 43E+02 2. 87E+02 1. 47E+02 1.21E+03 3.10E+03 Off-gas flow rate 13 scfm 0 >Ãt 9-23-80 4.72K+04 1.76E+04 8.87E+03 6.44E+03 2.62E+04 1.45E+04 Off-gas flow rate 50 scfm 3265 11Wt Unit 2 Reactor Water Iodines uCi/sec.)

Date I-131 I-132 I-133 I-134 I-135 9-04-80 3.36E+00 1.74E+01 6.40E+00 2.25E+01 1.04E+01 9-22-80 (Unit Outage)

Fission Gases at Dischar e of SJAE uCi/sec.)

Date Xe-138 Kr-87 Kr-88 Kr-85m Xe-135 Xe-133 9-02-80 9.52E+03 1.42E+03 8.16E+02 6.06E+02 2.08E+03 6.97E+02 Off-gas flow rate 120 scfm 2985 Mit 9-23-80 (Unit Outage)

Off-gas flow rate 0 scfm 0 M<t

107 Fuel Claddin Inte rit parameters (Continued)

September 1980 Unit 3 Reactor Water Iodines (uCi/sec.)

Date I-131 I-132 I-133 I-134 I-135 9-04-80 3.28E+01 2. 26E+02 5.49E+01 1.79E+02 9.23E+01 9-22-80 6.67E+00 l. 22E+01 7.04E+00 2.94E+Ol 9.64E+00 Fission Gases at Dischar e of SJAE (uCi/sec.)

Date Xe-138 Kr-87 Kr-88 Kr-85m Xe-135 Xe-133 9-02-80 3.27E+03 3.29E+02 1.62E+02 <4.86E+00. 4.62E+02 3.03E+02 Off-gas flow rate 42 scfm 2497 HWt 9-23-80 5.48E+03 6.83E+02 3.48E+02 2.09E+02 8.04E+02 2.24E+02 Off-gas flow rate 80 scfm 3018 MWt

j w r

. 1980 Year THROUGHPUTS (1)

WASTE TREATMENT SYSTEM VOLUME (2) September Month FLOOR TO CANAL FLOOR

9. 47E+04 DRAIN FLOOR DRAIN 1.40E+04 2.53E+04 d 'RPLE gpd gpdd COLLECTOR DRAIN FILTER TANK

[ 2. 84E+06 ]

TANK

[ 4.19E+05 ] [ 7.58E+05 ]

3 756

[ 2. 84E+06 ]

LAUNDRY DRAIN 7~27 E+0

[2. 18E+05

~pd

[ 0 TANK ]

[ 2. 42E+06 ]

EVAPORATOR 0'pd 0 gpf DISTILLATE

'2 . 00E+06 TANK 4,03E+03 gpd [0 ]

[ 1.21K+05 ]

WASTE WASTE CONDENSATE WASTE WASTE ~2.14K+05 pd 2.10E+05 gpd COLLECTOR SAMPLE STORAGE TANK FILTER DEMINERALIZE TANK TANK (4) [6.42E+06 ] [ 6.30K+06 ]

308 130 ft

[6. 42E+06 ] (9-17-80) gpd evetage gallons pet day (1))Represents 30 days Values accurate to two (2) signifjcant figures [ ] total gallons 240 Ft3 of powdered resins 516 Ft of mixed resin/filter media 3

116 Ft of powdered resins 192 'Ft of mixed resin/filter media (p ) 3

'P 109 WATER TREADKNT CHEMICAL USE Browns Ferr Nuclear Plant Month Year September 198,0 CHEMICALS REQUIRED DESCRIPTION AMOUNT Grade, concentration  %, Pounds, Gallons, Cuft, etc.

Anh drous etc.

This Month/Year To Date BOILER WATER MAKEUP TREATifENT Aluminum Sulfate 2700 lbs 8700 lbs Anthracite (filter media)

Coagulant aid, Polyelectrolyte (Wisprofloc 20)

Sodium hydroxide 11. 9 tons 65.8 tons Sulfuric acid, demineralizer 8.2 tons 65.9 tons Coagulant liquid polymer (Magnifloc 575-C) 1000 lbs BOILER WATER SECONDARY TREATMENT Ammonium hydroxide 1 gal 13 gal Hydrazine, hydrate 1 gal 12 gal Powdex, PAO (Wet) 20,790 lbs 111,870 lbs Powdex, PCH (Wet) 51,650 lbs 272,650 lbs Resins, bead type (stator cooling) 19 Cu Ft 28 CU Ft Celite, Supergel HSC 1,200 lbs 19,900 lbs Epicor PD-1 anion (Dry) 192 Cu Ft 4,056 Cu Ft Epicor PD-3 cation (Dry) 216 CU Ft 5,496 Cu Ft Epicor AC-31 Mixed Bed (Gravex Mixed Bed) 196 Cu Ft 2,112 Cu Ft Epifloc-Waste Filter Graver Ecocote-condensate 1,044 Cu Ft Graver Ecodex-Fuel Pool &

Waste Filter 1,088 Cu Ft 3,788 Cu Ft MISCELLANEOUS WATER TREATMENT (Includes sample and bearing cooling water systems, ash pond treatment, and other water systems, i.e., radwaste systems and fuel pool cleanup systems at nuclear plants requiring treatment.)

Sodium Nitrite (RBCCW and and Off Gas chiller) 450 lbs SEWAGE TREATMENT Sodium Hypochlorite 620 gal 1,575 gal Soda Ash 5,500 lbs

0 cI 0 0 4J Total Pla>>nt Training Summary

(>> 0 Cg

>>>> (>>

'u~

~

(4 Se tember 1980 (>> (>>

X Nonth Year >>>> 0 6 C4 (t>

0 (>>

pl U 0 I>

U W 0

(>> U II.P. Chemical 4J '0 t>>

0 0 (J>

SecLion OI>eraLor Ra(Iiological II.P. Laboratory I>>> 4J Traini>>g )Iygiene Retraining 'ualification Fire N.E. I.H. (lI Trai>>ing (3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />) Training Training Training Training Cl

(>>(>

(>>

(8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />) I>>>>> Cl llea 1 th

~Vh sic>> 10 I:.lee t ca 1ri II;Ii >> tenance 14

.Plcch;>ni c;>1 ll>>l I.l>LC>>>>l>>ce OI>el >>>Liolls 22 II>>:I I I Ly

>1ssllr>>lllc('0 IIes>>l ts h(lm>>s Lr tv 24 I >>>>Lr C(>>> t r(> I.s 10 33 I'ub I ic.

S>>JII cL'y I'00 I o(J('

."L(>rc'.: ....2 .

I'>>>(J(' >>>>y'I-I ('I>>l I >I>> (' >>

I>l.h>> 131 Total 69 245 7 47 24

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