ML18153A669

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Monthly Operating Repts for Oct 1995 for Surry Power Station Units 1 & 2.W/951113 Ltr
ML18153A669
Person / Time
Site: Surry  Dominion icon.png
Issue date: 10/31/1995
From: Mason D, Saunders R
VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.)
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
95-582, NUDOCS 9511200058
Download: ML18153A669 (21)
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Text

  • VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 November 13, 1995 U. S. Nuclear Regulatory Commission Serial No.95-582 Attention: Document Control Desk NO/RPC:vlh Washington, D. C. 20555 Docket Nos. 50-280 50-281 License Nos. DPR-32 DPR-37 Gentlemen:

VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNITS 1 AND 2 MONTHLY OPERATING REPORT Enclosed is the Monthly Operating Report for Surry Power Station Units 1 and 2 for the month of October 1995.

Very truly yours, R. F. Saunders Vice President - Nuclear Operations Enclosure cc: U.S. Nuclear Regulatory Commission Region II 101 Marietta Street, N. W.

Suite 2900 Atlanta, Georgia 30323 Mr. M. W. Branch NRG Senior Resident Inspector Surry Power Station 9511200058 951031 PDR ADOCK 05000280 R PDR

VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION MONTHLY OPERATING REPORT REPORT No. 95-10 Approved:

_..c::J~~, Sl~C~C..L:::::::.. -=--~'t - *,~, r Station Manager Date L_

  • .Surry Monthly Operating Report No. 95-10 Page 2 of 20 TABLE OF CONTENTS Section Page Operating Data Report - Unit No. 1 .........................................................................................................3 Operating Data Report- Unit No. 2 ......................................................................................................... 4 Unit Shutdowns and Power Reductions - Unit No. 1.................... , ............................................................... 5 Unit Shutdowns and Power Reductions - Unit No. 2 .................................................................................... 6 Average Daily Unit Power Level - Unit No. 1.............................................................................................. 7 Average Daily Unit Power Level - Unit No. 2 .............................................................................................. 8 Summary of Operating Experience - Unit No. 1 ......................................................................................... 9 Summary of Operating Experience - Unit No. 2 ......................................................................................... 9 Facility Changes That Did Not Require NRG Approval ............................................................................... 1O Procedure or Method of Operation Changes That Did Not Require NRG Approval ........................................... 15 Tests and Experiments That Did Not Require NRG Approval ...................................................................... 17 Chemistry Report ............................................................................................................................. 18 Fuel Handling- Unit No.1 ................................................................................................................... 19 Fuel Handling- Unit No. 2 ................................................................................................................... 19 Description of Periodic Test(s) Which Were Not Completed Within the Time Limits*

Specified in Technical Specifications ................................................................................................... 20

  • . r r y _Monthly Operating Report No. 95-10 Page 3 of 20 OPERATING DATA REPORT Docket No.: 50-280 Date: 11-01-95 Completed By: D. Mason Telephone: (804) 365-2459
1. Unit Name: .................................................. . Surry Unit 1
2. Reporting Period: ......................................... . October, 1995
3. Licensed Thermal Power (MWt): ...................... . 2441
4. Nameplate Rating (Gross MWe): ...................... . 847.5
5. Design Electrical Rating (Net MWe): ................. . 788
6. Maximum Dependable Capacity (Gross MWe): ... . 820
7. Maximum Dependable Capacity (Net MWe): ....... . 781
8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:
9. Power Level To Which Restricted, If Any (Net MWe):
10. Reasons For Restrictions, If Any:

This Month YTD Cumulative

11. Hours In Reporting Period .......................... 745.0 7296.0 200376.0
12. Number of Hours Reactor Was Critical .......... 294.0 6117.0 136586.7
13. Reactor Reserve Shutdown Hours ............... 0 0 3774.5
14. Hours Generator On-Line ........................... 254.1 6042.0 134283.0
15. Unit Reserve Shutdown Hours ..................... 0 0 3736.2
16. Gross Thermal Energy Generated (MWH) ...... 499688.2 14254410.4 312708149.6
17. Gross Electrical Energy Generated (MWH) .... 164820.0 4731750.0 102345583.0
18. Net Electrical Energy Generated (MWH) ........ 158313.0 4554512.0 97263535.0
19. Unit Service Factor ................................... 34.1% 82.8% 67.0%
20. Unit Availability Factor ............................... 34.1% 82.8% 68.9%
21. Unit Capacity Factor (Using MDC Net) ........... 27.2% 79.9% 62.6%
22. Unit Capacity Factor (Using DER Net) ........... 27.0% 79.2% 61.6%
23. Unit Forced Outage Rate ............................ 0.0% 3.4% 16.2%
24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):
25. If Shut Down at End of Report Period, Estimated Date of Start-up:
26. Unit In Test Status (Prior to Commercial Operation):

FORECAST ACHIEVED INITIAL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION

  • . r r y Monthly Operating Report No. 95-10 Page 4 of 20 OPERATING DATA REPORT Docket No.: 50-281 Date: 11-01-95 Completed By: D. Mason Telephone: (804) 365-2459
1. Unit Name: .................................................. . Surry Unit 2
2. Reporting Period: ......................................... . October, 1995
3. Licensed Thermal Power (MWt): ...................... . 2546
4. Nameplate Rating (Gross MWe): ...................... . 847.5
5. Design Electrical Rating (Net MWe): ................. . 788
6. Maximum Dependable Capacity (Gross MWe): ... . 840
7. Maximum Dependable Capacity (Net MWe): ....... . 801
8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:
9. Power Level To Which Restricted, If Any (Net MWe):
10. Reasons For Restrictions, If Any:

This Month YTD Cumulative

11. Hours In Reporting Period .......................... 745.0 7296.0 197256.0
12. Number of Hours Reactor Was Critical .......... 745.0 6051.6 134389.1
13. Reactor Reserve Shutdown Hours ............... 0 0 328.1
14. Hours Generator On-Line ........................... 745.0 5981.7 132448.8
15. Unit Reserve Shutdown Hours ..................... 0 0 0
16. Gross Thermal Energy Generated (MWH) ...... 1894050.9 14469126.3 .309737590.6
17. Gross Electrical Energy Generated (MWH) .... 623790.0 4782260.0 101224554.0
18. Net Electrical Energy Generated (MWH) ........ 604676.0 4614765.0 96207801.0
19. Unit Service Factor ................................... 100.0% 82.0% 67.1%
20. Unit Availability Factor ............................... 100.0% 82.0% 67.1%
21. Unit Capacity Factor (Using MDC Net) ........... 101.3% 80.6% 62.5%
22. Unit Capacity Factor (Using DER Net) ........... 103.0% 80.3% 61.9%
23. Unit Forced Outage Rate ............................ 0.0% 3.3% 12.9%
24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):
25. If Shut Down at End of Report Period, Estimated Date of Start-up:
26. Unit In Test Status (Prior to Commercial Operation):

FORECAST ACHIEVED INITIAL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION

  • Surry Monthly Operating Report No. 95-10 Page 5 of 20 UNIT SHUTDOWN AND POWER REDUCTION (EauAL To OR GREATER THAN 20%)

REPORT MONTH: October, 1995 Docket No.: 50-280 Unit Name: Surry Unit 1 Date: 11-04-95 Completed by: Craig Olsen Telephone: (804) 365-2155 (1) (2) (3) (4) (5)

Method Duration of LER System Component Cause & Corrective Action to Date Type Hours Reason Shutting No. Code Code Prevent Recurrence Down Rx None During the Reporting Period (1) (2) (3)

F: Forced REASON: METHOD:

S: Scheduled A - Equipment Failure (Explain) 1 - Manual B Maintenance or Test 2 - Manual Scram.

C Refueling 3 - Automatic Scram.

D Regulatory Restriction 4 - Other (Explain)

E Operator Training & Licensing Examination F Administrative G Operational Error (Explain)

(4) (5)

Exhibit G - Instructions for Preparation of Data Entry Sheets Exhibit 1 - Same Source.

for Licensee Event Report (LER) File (NUREG 0161)

  • Surry Monthly Operating Report No. 95-10 Page 6 of 20 UNIT SHUTDOWN AND POWER REDUCTION (EQUAL To OR GREATER THAN 20%)

REPORT MONTH: October, 1995 Docket No.: 50-281 Unit Name: Surry Unit 2 Date: 11-04-95 Completed by: Craig Olsen Telephone: (804) 365-2155 *

(1) (2) (3) (4) (5)

Method Duration of LER System Component Cause & Corrective Action to Date Type Hours Reason Shutting No. Code Code Prevent Recurrence Down Rx None During the Reporting Period (1) (2) (3)

F: Forced REASON: METHOD:

S: Scheduled A - Equipment Failure (Explain) 1 - Manual B Maintenance or Test 2 Manual Scram.

C Refueling 3 - Automatic Scram.

D Regulatory Restriction 4 - Other (Explain)

E Operator Training & Licensing Examination F Administrative G Operational Error (Explain)

(4) (5)

Exhibit G - Instructions for Preparation of Data Entry Sheets Exhibit 1 - Same Source.

for,Licens~,Ev,ent Report (LER) File (NUREG 0161)

  • Surry Monthly Operating Report No. 95-10 Page 7 of 20 AVERAGE DAILY UNIT POWER LEVEL Docket No.: 50-280 Unit Name: Surry Unit 1 Date: 11-08-95 Completed by: Barry C. Bryant Telephone: (804) 365-2786 MONTH: October, 1995 Average Daily Power Level Average Daily Power Level Day (MWe-Net) Day (MWe-Net) 1 0 17 0 2 0 18 0 3 0 19 0 4 0 20 0 5 0 21 93 6 0 22 204 7 0 23 245 8 0 24 460 9 0 25 644 10 0 26 805 11 0 27 822 12 0 28 822 13 0 29 823 14 0 30 823 15 0 31 822 16 0 INSTRUCTIONS On this format, list the average daily unit power level in MWe - Net for each day in the reporting month. Compute to the nearest whole megawatt:, * *
  • .Surry Monthly Operating Report No. 95-10 Page 8 of 20 AVERAGE DAILY UNIT POWER LEVEL Docket No.: 50-281 Unit Name: Surry Unit 2 Date: 11-08-95 Completed by: Barry C. Bryant Telephone: (804) 365-2786 MONTH: October, 1995 Average Daily Power Level Average Daily Power Level Day (MWe-Net) Day (MWe-Net) 1 792 17 816 2 814 18 788 3 817 19 802 4 818 20 804 5 817 21 817 6 811 22 818 7 790 23 818 8 810 24 809 9 813 25 819 10 811 26 820 11 808 27 821 12 812 28 821 13 816 29 821 14 815 30 821 15 815 31 791 16 816 INSTRUCTIONS On this format, list the average daily unit power level in MWe - Net for each day in the reporting month. Compute to the nearest whole megawatt.
  • tltsurry Monthly Operating Report No. 95-10 Page 9 of 20

SUMMARY

OF OPERATING EXPERIENCE MONTHIYEAR: October, 1995 The following chronological sequence by unit is a summary of operating experiences for this month which required load reductions or resulted in significant non-load related incidents.

UN!IONE:

10/01/95 0000 The reporting period began with the unit at refueling shutdown.

10/19/95 1900 Reactor critical.

10/21/95 1056 Generator on line. Started power increase.

1157 Stopped power increase at 30%, 255 MWe 10/22/95 1352 Started power increase.

1700 Stopped power increase at 37%, 315 MWe due to main condenser tube rupture.

1739 Started power reduction due to entry into secondary chemistry Action Level 11.

1800 Stopped power reduction at 30%, 255 MWe 10/23/95 1457 Started power increase.

\

1938 Stopped power increase at 50%, 425 MWe.

10/24/95 1645 Started power increase. .

2200 Stopped power increase at 70%, 590 MWe.

10/25/95 0830 Started power increase.

1420 Stopped power increase at 83%, 716 MWe.

2003 Started power increase 10/26/95 0048 Stopped power increase at 96%, 814 MWe.

0755 Started power increase 1648 Stopped power increase at 100%, 853 MWe 10/31/95 2400 The reporting period ended with the unit operating at 100% power, 853 MWe.

UN11Jwo:

10/01/95 0000 The reporting period began with the unit operating at 100% power, 840 MWe.

10/31/95 0530 Started power reduction to maintain condenser vacuum while "B" waterbox was removed from service.

0555 Stopped power reduction at 97%, 800 MWe.

1935 Started power increase.

1955 Stopped power increase at 100%, 855 MWe.

2400 The reporting period ended with the unit operating at 100% power, 855 MWe.

  • FACILITY CHANGES THAT DID NOT tllrry Monthly Operating Report No. 95-10 Page 10 of 20 REQUIRE NRC APPROVAL MONTHNEAR: October, 1995 DCP 93-080-1 Design Change Package 10-01-95 (Safety Evaluation No.94-014)

Design Change Package 93-080-1 changed the thermal overloads for a number of Unit 1 safety-related motor-operated valves (MOVs) to a different size and/or setting to assure operation of the MOVs under conditions in accordance with the requirements of Generic Letter 89-10.

The modifications implement industry standards for setting thermal overloads to ensure that the MOV motor will not experience a failure as a result of operation during accident conditions. The changes will improve the reliability of the MOVs by improving the ability for the MOVs to be operated additional times. The changes did not affect the ability of the valves to perform their safety functions or reduce the margin of safety. Therefore, an unreviewed safety question does not exist.

DCP 94-066-3 Design Change Package 10-03-95 (Safety Evaluation No.95-069)

Design Change Package (DCP) 94-066-3 redesigned the flow instrumentation for the service water (SW) to the control and relay room chiller condensers located in Mechanical Equipment Room No. 3. The new design included the installation of V-cone flow elements in the chiller condenser SW discharge lines and the replacement of existing suction and discharge local pressure indicators for the chiller condenser SW pumps.

The new design improved the capability to accurately and reliably monitor the flow of SW through the control and relay room chiller condensers. The modifications did not adversely impact the operational performance of the SW system or components cooled by the SW system. Therefore, an unreviewed safety question does not exist.

DCP 87-022-1 Design Change Package 10-05-95 Design Change Package (DCP) 87-022-1 replaced the Unit 1 recirculating spray heat exchangers, the discharge piping for the outside recirculating spray pumps, and the associated service water inlet elbows.

The new heat exchangers and piping meet or exceed original design requirements. The material composition of the new heat exchangers is superior to that of the original heat exchanger. The performance characteristics of the Recirculating Spray system were not altered by this DCP. Therefore, an unreviewed safety question does not exist.

DCP 95-036-1 Design Change Package 10-05-95 (Safety Evaluation No.95-132, Revision 1)

Design Change Package (DCP) 94-036-1 replaced the instrument nozzles on the Unit 1 pressurizer.

The replacement nozzles were fabricated from material that exhibits mechanical and chemical properties comparable to that of the original nozzles. An analysis of the new nozzles concluded that the design did not affect the existing design analysis of the pressurizer and thus, did not affect the Technical Specifications margin of safety.

Therefore, an unreviewed safety question does not exist.

  • FACILITY CHANGES THAT DID NOT

. r r y Monthly Operating Report No. 95-10 Page 11 of 20 REQUIRE NRC APPROVAL MONTHNEAR: October, 1995 DR S-95-2353 Deviation Report 10-10-95 (Safety Evaluation No.95-140)

Safety Evaluation No.95-140 assessed the condition reported by Deviation Report S-95-2353 concerning localized liquid penetrant indications and areas on the inside wall of the Unit 1 pressurizer at which little or no austentic stainless steel cladding remains. The thickness of the cladding was reduced by grinding efforts to remove the liquid penetrant indications.

The evaluation concluded that the cladding flaws and localized reduction in cladding thickness is acceptable since the cladding flaws will not affect the structural integrity of the pressurizer and since any exposed base metal will not be significantly affected by corrosion. The pressurizer is fully operable with the minor cladding flaws and the margin of safety is not changed. Therefore, an unreviewed safety question does not exist.

DR S-95-2190 Deviation Reports 10-10-95 DR S-95-2393 (Safety Evaluation No.95-141)

DR S-95-2394 Safety Evaluation No.95-141 assessed the condition reported by Deviation Reports S 2190, S-95-2393, and S-95-2394 concerning the separation of steam generator tube plug tops from the plug bodies. The plug tops became separated from the plug bodies when the plugs were being removed from the Unit 1 Steam Generator.

The evaluation concluded that the remaining plug tops do not represent a modification of any portion of the pressure boundary, do not alter the function of the steam generator, and do not adversely affect any connecting system or component. Therefore, an unreviewed safety question does not exist.

TM S1-95-22 Temporary Modification 10-12-95 (Safety Evaluation No.95-146)

Temporary Modification S1-95-22 installed electrical jumpers to bypass test switch LC-474-TB on the Unit 1 Safety Injection (SI) Train "B" circuitry to allow the switch to be replaced without rendering the circuits inoperable.

SI Train "A" was not affected by this activity and both trains remained capable of operating as designed. Double verification of jumper installation/removal and post-maintenance testing were performed. Therefore, an unreviewed safety question does not exist.

TM S1-95-23 Temporary Modification 10-12-95 (Safety Evaluation No.95-148)

Temporary Modification S 1-95-23 installed electrical jumpers to bypass test switch LC-495-TA on the Unit 1 Safety Injection (SI) Train "A" circuitry to allow the switch to be replaced without rendering the circuits inoperable.

SI Train "B" was not affected by this activity and both trains remained capable of operation as designed. Double verification of jumper installation/removal and post-maintenance testing were performed. Therefore, an unreviewed safety question does not exist.

  • FACILITY CHANGES THAT DID NOT llrry Monthly Operating Report No. 95-10 Page 12 of 20 REQUIRE NRC APPROVAL MONTHNEAR: October, 1995 TM S1-95-24 Temporary Modification 10-12-95 (Safety Evaluation No.95-145)

Temporary Modification S1-95-24 installed electrical jumpers to bypass test switch TC-432E-TB on the Unit 1 Safety Injection (SI) Train "B" circuitry to allow the switch to be replaced without rendering the circuits inoperable.

SI Train "A" was not affected by this activity and both trains remained capable of operating*

as designed. Double verification of jumper installation/removal and post-maintenance testing were performed. Therefore, an unreviewed safety question does not exist.

TM S1-95-25 Temporary Modification 10-12-95 (Safety Evaluation No.95-149)

Temporary Modification S1-95-25 installed electrical jumpers to bypass test switch P-7XA on the Unit 1 Reactor Protection System (RPS) Train "A" circuitry to allow the switch to be replaced without rendering the circuits inoperable.

RPS Train "B" was not affected by this activity and both trains remained capable of operating as designed. The activity was performed while the unit was at Cold Shutdown. -

Double verification of jumper installation/removal and post-maintenance testing were performed. Therefore, an unreviewed safety question does not exist.

TM S1-95-26 Temporary Modification 10-12-95 (Safety Evaluation No.95-147)

Temporary Modification S1-95-26 installed electrical jumpers to bypass test switch P-10 on the Unit 1 Reactor Protection System (RPS) Train "A" circuitry to allow the switch to be replaced without rendering the circuits inoperable.

RPS Train "B" was not affected by this activity and both trains remained capable of operating as designed. The activity was performed while the unit was at Cold Shutdown.

Double verification of jumper installation/removal and post-maintenance testing were performed. Therefore, an unreviewed safety question does not exist.

DCP 94-010-3 Design Change Package 10-13-95 (Safety Evaluation No.94-154)

Design Change Package (DCP) 94-010-3 changed the 500 kV switchyard alignment from a ring to a breaker-and-a-half arrangement, with the addition of a 500 kV breaker. The DCP also removed the 34.5 kV shunt reactor banks and associated circuit breakers, relay panels, and vacuum switches.

The new arrangement provides more stability to Generator No. 2 and Transformer No. 1.

The margin of safety as defined in the bases of the Technical Specifications is not reduced since the modifications enhanced the 500 kV switchyard and since reliable offsite power can continue to be maintained without the shunt reactors. Therefore, an unreviewed safety question does not exist.

  • FACILITY CHANGES THAT DID NOT

. r r y Monthly Operating Report No. 95-10 Page 13 of 20 REQUIRE NRC APPROVAL MONTH/YEAR: October, 1995 DCP 94-055-1 Design Change Package 10-13-95 (Safety Evaluation No.95-039)

Design Change Package (DCP) 94-055-1 replaced Unit 1 feedwater flow elements 1-FW-FE-1476, 1-FW-FE-1486 and 1-FW-FE-1496 and adjoining piping with new flow elements and piping constructed of erosion/corrosion resistant materials.

The new piping and flow elements were hydrostatically tested following installation and the feedwater flow instrument loops were recalibrated. This modification was essentially a one-for-one replacement of an enhanced design and did not affect the operation or ability of the equipment to perform its intended function. Therefore, an unreviewed safety question does not exist.

TM S1-95-27 Temporary Modification 10-13-95 (Safety Evaluation No.95-150)

Temporary Modification S1-95-27 installed electrical jumpers to bypass test switch FC-484-TB on the Unit 1 Safety Injection (SI) Train "B" circuitry to allow the switch to be replaced without rendering the circuits inoperable.

SI Train "A" was not affected by this activity and both trains remained capable of operating as designed. Double verification of jumper installation/removal and post-maintenance testing were performed. Therefore, an unreviewed safety question does not exist.

TM S1-95-28 Temporary Modification 10-14-95 (Safety Evaluation No.95-151)

Temporary Modification (TM) S1-95-28 maintained the Primary Drains Transfer Tank (POTT) pressure control valve, 1-DG-PCV-100, in the open position to eliminate spurious High Flux at Shutdown alarms caused by electrical noise generated when 1-DG-SOV-100 energizes to open 1-DG-PCV-100.

The TM was in place while the unit was at Cold Shutdown or Refueling Shutdown with the containment at atmospheric conditions. At these conditions, the Primary Drains System functioned normally. Containment isolation capability was unaffected by this TM.

Therefore, an unreviewed safety question does not exist.

DCP 94-007-3 Design Change Package 10-15-95 (Safety Evaluation No.94-144)

Design Change Package (DCP) 94-007-3 eliminated the Load Limit and Load Reference turbine runbacks for a dropped control rod condition and the automatic rod withdrawal blocking for a dropped rod.

  • These modifications implemented the revised Westinghouse dropped rod analysis methodology (i.e., WCAP-11394), which has been incorporated into the core reload process for Surry. The new methodology takes no credit for the subject runback and rod withdrawal blocking functions and does not alter the actual or predicted consequences or affect the probability of occurrence of the dropped rod event. Therefore, an unreviewed safety question does not exist.
  • FACILITY CHANGES THAT DID NOT

. r r y Monthly Operating Report No.95-10 Page 14 of 20 REQUIRE NRC APPROVAL MONTHNEAR: October, 1995 DCP 94-024-3 Design Change Package 10-16-95 (Safety Evaluation No.94-130)

Design Change Package 94-024-3 installed an undervoltage bypass switch in the main control room for the turbine-driven auxiliary feedwater pump (TDAFWP) steam supply ..

pressure control valves (PCV).

The undervoltage bypass switch permits remote control of the steam supply to the TDAFWP during an undervoltage on 2 out of 3 station service buses condition or a loss of all AC power condition. The modification was consistent with related NUREG-0737 commitments and did not affect the performance characteristics of the TDAFWP. The change did not reduce the capacity and design basis of safety used to mitigate any of the postulated accidents. Therefore, an unreviewed safety question does not exist.

DR S-95-2324 Deviation Report 10-19-95 (Safety Evaluation No. 95-153A)

Safety Evaluation No. 95-153A assessed the condition reported by Deviation Report S-95-2324 concerning excessive leakage from the Unit 2 Reactor Coolant Pump (RCP) 2-RC-P-1 C No. 2 seal.

The evaluation concluded that the RCP seal is capable of performing its intended function since the No. 2 seal will mitigate leakage flow in the event of a failure of the No. 1 (primary) seal. Procedures are in place to ensure that the total No. 1 seal leak-off flow is monitored and that the total leakage criteria of the Technical Specifications continues to be met.

Therefore, an unreviewed safety question does not exist.

SE 95-154 Safety Evaluation 10-20-95 Safety Evaluation 95-154 was performed to evaluate Unit 1 operation with pressurizer spray control valve 1-RC-PCV-14558 maintained in a fully closed position. The subject valve would not close fully on demand during the last Unit 1 startup, resulting in unacceptable leakage into the Reactor Coolant System. The valve was mechanically closed and the instrument air to the valve operator was isolated.

The evaluation concluded that operation with one pressurizer spray valve closed and disabled will not invalidate any of the UFSAR Chapter 14 safety analyses. Therefore, an unreviewed safety question does not exist.

WO 00328499 01 Work Order 10-20-95 (Safety Evaluation No.95-153, Revision 1)

Work Order 00328499 01 performed an on-line temporary leak-seal repair of Unit 1 "B" Steam Generator Slowdown Drain Valve 1-80-12. The valve was sealed in the closed position to eliminate system leakage past the valve body and bonnet.

An evaluation of this activity concluded that the leak sealant material is acceptable for the temperature/pressure of the fluid medium and potential area radiation levels. The repair will not adversely affect the pressure boundary function of the subject valve, which is normally closed during unit operation. Therefore, an unreviewed safety question does not exist.

PROCEDURE OR METHOD OF OPERATION CHANGES

. r r y Monthly Operating Report No. 95-10 Page 15 of 20 THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: October, 1995 FDTP-92-052-3-8 Final Design Test Procedure 10-05-95 (Safety Evaluation No.95-128, Revision 1)

Final Design Test Procedure FDTP-92-052-3-8 was developed to provide instructions for functionally testing the Station Blackout (SBO) Diesel Generator to verify that the requirements of 10 CFR 50.63 and Regulatory Guide 1.155 are met.

The testing will be conducted with Unit 1 at Refueling Shutdown. The No. 1 and No. 2 Emergency Diesel Generators will be fully operable. Therefore, an unreviewed safety question does not exist.

1[2]-ES-0.2 Emergency Operating Procedures 10-10-95 1[2]-ES-3.1 (Safety Evaluation No.93-224, Revision 1) 1[2]-ES-3.2 1[2]-ES-3.3 Emergency Operating Procedures 1[2]-ES-0.2, "Natural Circulation Cooldown,"

1[2]-ES-3.1, "Post-SGTR Cooldown Using Backfill," 1[2]-ES-3.2, "Post-SGTR Cooldown Using Slowdown," and 1[2]-ES-3.3, "Post-SGTR Cooldown Using Steam Dump," were revised to provide instructions for installing electrical jumpers to defeat the delta-T and valve position interlocks of the Reactor Coolant system loop stop valves.

This procedurally controlled temporary modification enables the subject valves to be removed from their backseats following a reactor trip in order to prevent potential valve damage that may occur during the cooldown process. The procedural controls ensure that the valves will not be closed. Valve movement is limited to moving from the backseat. Double verification of jumper installation/removal and post maintenance testing will be performed. Therefore, an unreviewed safety question does not exist.

1-0P-Sl-002 Operating Procedure 10-10-95 (Safety Evaluation No.95-142)

Operating Procedure 1-0P-Sl-002, "Safety Injection Accumulators", was revised to provide instructions for installing a temporary mechanical jumper to permit the Unit 1 refueling water storage tank recirculation pumps to be used to fill the Safety Injection (SI)

System accumulators.

The procedure allows the mechanical jumper to be installed while the unit is at cold/refueling shutdown when the SI System is not required. The jumper will be rated for the pressure of the associated piping flow path, inspected for leakage after it is placed in service, and removed before the unit leaves cold shutdown. Therefore, an unreviewed safety question does not exist.

PROCEDURE OR METHOD OF OPERATION CHANGES

. r r y Monthly Operating Report No. 95-10 Page 16 of 20 THAT DID NOT REQUIRE NRC APPROVAL MoNTHNEAR: October, 1995 1-NPT-RX-002 Engineering Periodic Test Procedure 10-21-95 (Safety Evaluation No.95-155)

Engineering Periodic Test Procedure 1-NPT-RX-002, "Flux Maps," was temporarily changed to provide instructions for installing an electrical jumper around the limit switch for the detector withdrawn position on the Unit 1 "A" incore detector drive motor. This jumper will allow use of the "A" detector 10 path transfer device to perform Technical Specifications required full core flux maps. The "A" detector 5 path transfer switch will also be disabled to prevent damaging the detector cable when the detector is inserted into its storage location.

This change will facilitate the continued performance of full core flux mapping and will prevent unnecessary radiation hazards. Furthermore, operation of the incore instrumentation system will not be adversely affected and the integrity of the reactor coolant system boundary at the seal table will not be compromised. Therefore, an unreviewed safety question does not exist.

2-TOP-4067 Temporary Operating Procedure 10-24-95 (Safety Evaluation No.95-156)

Temporary Operating Procedure 2-TOP-4067, "Reactor Coolant Pump 2-RC-P-1C Seal Leakoff Vent Procedure," was developed to provide instructions for venting the Reactor Coolant Pump (RCP) 2-RC-P-1 C No. 1 seal leakoff connection to backflush the No. 2 seal.

The procedure included administrative controls to ensure that seal leakoff flow was not isolated during the activity and to ensure that the vent valve would be closed promptly in the event of a seal failure. This activity did not affect the operation of RCP 2-RC-P-1 C or the Reactor Coolant System pressure boundary. Therefore, an unreviewed safety question does not exist.

O-MCM-0814-01 Mechanical Corrective Maintenance Procedure 10-31-95 (Safety Evaluation No.95-159)

Mechanical Corrective Maintenance Procedure O-MCM-0814-01, "Control Room Chiller Maintenance," was revised to provide instructions for the installation, operation, and removal of electrical jumpers to enable the chiller compressor to be used to assist in the addition or removal of freon to/from the main control room chillers.

The affected chiller will be inoperable during the implementation of the subject procedure.

Chiller availability will be maintained using parallel operable chillers in accordance with Technical Specifications. Therefore, an unreviewed safety question does not exist.

  • .Surry Monthly Operating Report TESTS AND EXPERIMENTS THAT DID NOT REQUIRE NRC APPROVAL No. 95-10 Page 17 of 20 MoNTHIYEAR: October, 1995 None During the Reporting Period

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e Surry Monthly Operating Report No. 95-10 Page 18 of 20 CHEMISTRY REPORT MoNTHIYEAR: October, 1995 Unit No. 1 Unit No. 2 Primary Coolant Analysis Max. Min. Avg. Max. Min. Avg.

Gross Radioactivitv, uCi/ml 3.89E-1 1.53E-3 6.40E-2 2.41 E-1 1.27E-1 1.84E-1 Suspended Solids, ppm 0.250 S0.01 0.109 S0.01 S0.01 S0.01 Gross Tritium, uCi/ml 9.56E-2 2.21E-2 5.89E-2 4.52E-1 3.23E-1 3.75E-1 1131 uCi/ml 8.82E-3 2.20E-5 4.19E-4 1.60E-4 1.06E-4 1.26E-4 113111133 0.07 0.06 0.07 0.10 0.06 0.08 Hvdroaen cc/kg 34.9 11.1 24.9 35.9 29.5 32.5 Lithium, com 3.14 0.10 1.87 2.33 2.05 2.19 Boron - 10, com* 484.7 224.5 366.9 150.1 134.8 141.9 Oxygen, (DO), ppm 9.0 S0.005 2.7 S0.005 S0.005 S0.005 Chloride, ppm S0.050 S0.001 0.007 S0.050 0.002 0.005 oH at 25 dearee Celsius 6.57 4.68 5.32 6.89 6.60 6.80

None

FUEL HANDLING

- Surry Monthly Operating Report No. 95-10 Page 19 of 20 UNITS 1 & 2 MoNTHIYEAR: October, 1995 New or Spent Number of New or Spent Fuel Shipment Date Stored or Assemblies Assembly ANSI Initial Fuel Shipping Number Received per Shipment Number Number Enrichment Cask Activity No Fuel Received or Stored During the Reporting Period

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e Surry Monthly Operating Report No. 95-10 Page 20 of 20 DESCRIPTION OF PERIODIC TEST(S) WHICH WERE NOT COMPLETED WITHIN THE TIME LIMITS SPECIFIED IN TECHNICAL SPECIFICATIONS MoNTHIYEAR: October, 1995 None During the Reporting Period

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