Text

Monthly Operating Repts for Jan 1995 for Surry Power Station Units 1 & 2
	ML18153B236
Person / Time
Site:	Surry
Issue date:	01/31/1995
From:	Christian D, Ohanlon J; VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.)
To:	; NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
	95-051, 95-51, NUDOCS 9502280003
	Download: ML18153B236 (20)
	v • d • e

e e

I VIRGINIA. ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 February 13, 1995 United States Nuclear Regulatory Commission Attention: Document Control Desk Washington, D. C. 20555 Gentlemen:

VIRGINIA ELECTRIC AND. POWER COMPANY.

SURRY POWER STATION UNITS 1 AND 2 MONTHLY OPERATING REPORT Serial No.95-051 NO/RPC:vlh Docket Nos. 50-280 50-281 License Nos. DPR-32 DPR-37 Enclosed is the Monthly Operating Report for Surry Power Station Units 1 and 2 for the month of January 1995.

Very truly yours,

~?~

James P. O'Hanlon Senior Vice President - Nuclear Enclosure cc:

U. S. Nuclear Regulatory Commission Region II 101 Marietta Street, N. W.

Suite 2900 Atlanta, Georgia 30323 Mr. M. W. Branch NRC Senior Resident Inspector Surry Power Station

__________ r;.; __

_________ _

9502280003 95013f ____

J' PDR ADOCK 05000280 R

PDR

VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION MONTHLY OPERATING REPORT REPORT No. 95-01 Approved:

Station Manager Z-1D-U Date

TABLE OF CONTENTS Section e

Surry Monthly Operating Report No. 95-01 Page 2 of 19 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 NRC Approval............................................................................... 10 Procedure or Method of Operation Changes That Did Not Require NRC Approval........................................... 13 Tests and Experiments That Did Not Require NRC Approval...................................................................... 16 Chemistry Report............................................................................................................................. 17 Fuel Handling - Unit No. 1................................................................................................................... 18 Fuel Handling - Unit No. 2................................................................................................................... 18 Description of Periodic Test(s) Which Were Not Completed Within the Time Limits Specified in Technical Specifications................................................................................................... 19

OPERATING DATA REPORT e Surry Monthly Operating Report No. 95-01 Page 3 of 19 Docket No.:

Date:

Completed By:

50-280 02-05-95 D. Mason Telephone:

(804) 365-2459 1. Unit Name:...................................................

2.

Reporting Period:..........................................

3.

Licensed Thermal Power (MWt):.......................

4.

Nameplate Rating (Gross MWe):.......................

5.

Design Electrical Rating (Net MWe):..................

6.

Maximum Dependable Capacity (Gross MWe):....

7. Maximum Dependable Capacity (Net MWe):........

Surry Unit 1 January, 1995 2441 847.5 788 820 781

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..........................

744.0 744.0 193824.0

12. Number of Hours Reactor Was Critical..........

599.9 599.9 131069.6

13.

Reactor Reserve Shutdown Hours...............

0 0

3774.5

14. Hours Generator On-Line...........................

571.1 571.1 128812.1

15. Unit Reserve Shutdown Hours.....................

0 0

3736.2

16. Gross Thermal Energy Generated (MWH)......

1385042.9 1385042.9 299838782.1

17. Gross Electrical Energy Generated (MWH)....

467185.0 467185.0 98081018.0

18. Net Electrical Energy Generated (MWH)........

450911.0 450911.0 93159934.0

19. Unit Service Factor...................................

76.8%

66.5%

20.

Unit Availability Factor...............................

76.8%

68.4%

21.

Unit Capacity Factor (Using MDC Net)...........

77.6%

62.0%

22.

Unit Capacity Factor (Using DER Net)...........

76.9%

61.0%

23.

Unit Forced Outage Rate............................

23.2%

16.7%

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 INITIAL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION ACHIEVED

e Surry Monthly Operating Report No. 95-01 Page 4 of 19 OPERATING DATA REPORT Docket No.:

Date:

Completed By:

50-281 02-05-95 D. Mason Telephone:

(804) 365-2459

1. Unit Name:...................................................

2.

Reporting Period:..........................................

3.

Licensed Thermal Power (MWt):.......................

4.

Nameplate Rating (Gross MWe):.......................

5.

Design Electrical Rating (Net MWe):..................

6.

Maximum Dependable Capacity (Gross MWe):....

7. Maximum Dependable Capacity (Net MWe ):........

Surry Unit 2 January, 1995 2441 847.5 788 820 781

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..........................

744.0 744.0 190704.0

12. Number of Hours Reactor Was Critical..........

744.0 744.0 129081.5

13.

Reactor Reserve Shutdown Hours...............

0 0

328.1

14. Hours Generator On-Line...........................

744.0 744.0 127211.1

15. Unit Reserve Shutdown Hours.....................

0 0

0

16. Gross Thermal Energy Generated (MWH)......

1714402.1 1714402.1 296982866.4

17. Gross Electrical Energy Generated (MWH)....

573985.0 573985.0 97016279.0

18. Net Electrical Energy Generated (MWH)........

552827.0 552827.0 92145863.0

19. Unit Service Factor...................................

100.0%

66.7%

20.

Unit Availability Factor...............................

100.0%

66.7%

21. Unit Capacity Factor (Using MDC Net)...........

95.1%

62.0%

22. Unit Capacity Factor (Using DER Net)...........

94.3%

61.3%

23.

Unit Forced Outage Rate............................

0%

13.2%

24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):

Refueling (1 o Year ISi), February 2, 1995, 53 Days *

25. If Shut Down at End of Report Period, Estimated Date of Start-up:

26. Unit In Test Status (Prior to Commercial Operation):

FORECAST INITIAL CRITICALITY ACHIEVED INITIAL ELECTRICITY COMMERCIAL OPERATION

Surry Monthly Operating Report No. 95-01 Page 5 of 19 UNIT SHUTDOWN AND POWER REDUCTION (EQUAL To OR GREATER THAN 20%)

REPORT MONTH: January, 1995 (1)

(2)

(3)

(4)

(5)

Method Docket No.:

50-280 Unit Name:

Surry Unit 1 Date: 02-05-95 Completed by:

Craig Olsen Telephone:

(804) 365-2155 Duration of LER System Component Cause & Corrective Action to Date Type Hours Reason Shutting No.

Code Code Prevent Recurrence 950108 F

172.9 (1)

F:

Forced S:

Scheduled A

(2)

REASON:

Down Rx 3

1 001-00 A -

Equipment Failure (Explain)

B Maintenance or Test C

Refueling D

Regulatory Restriction SL E

Operator Training & Licensing Examination F

Administrative G

Operational Error (Explain)

(4)

Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File (NUREG 0161)

LM Main Feedwater Pump 1-FW-P-1 B tripped due to low lube oil pressure to motor bearing, resulting from failed lube oil pipe coupling. Failed coupling was replaced.

(3)

METHOD:

1 -

Manual 2 -

Manual Scram.

3 -

Automatic Scram.

4 -

Other (Explain)

(5)

Exhibit 1 - Same Source.

(1)

Surry Monthly Operating Report No. 95-01 Page 6 of 19 UNIT SHUTDOWN AND POWER REDUCTION (EQUAL To OR GREATER THAN 20%)

REPORT MONTH: January, 1995 (2)

(3)

(4)

(5)

Docket No.:

50-281 Unit Name:

Surry Unit 2 Date:

02-05-95 Completed by:

Craig Olsen Telephone:

(804) 365-2155 Duration Method of Reason Shutting Down Rx LER No.

System Component Cause & Corrective Action to Date Type Hours Code Code Prevent Recurrence (1)

F:

Forced S:

Scheduled (4)

(2)

REASON:

None During the Reporting Period A -

Equipment Failure (Explain)

B Maintenance or Test C

Refueling D

Regulatory Restriction E

Operator Training & Licensing Examination F

Administrative G

Operational Error (Explain)

Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File (NU REG 0161)

(3)

METHOD:

1 -

Manual 2 -

Manual Scram.

3 -

Automatic Scram.

4 -

Other (Explain)

(5)

Exhibit 1 - Same Source.

Surry Monthly Operating Report No. 95-01 Page 7 of 19 AVERAGE DAILY UNIT POWER LEVEL Docket No.:

50-280 Unit Name:

Surry Unit 1 Date:

02-04-95 Completed by:

Pat Kessler Telephone: 365-2790 MONTH:

January, 1995 Average Daily Power Level Average Daily Power Level Day (MWe-Net)

Day (MWe-Net) 796 17 798 2

796 18 796 3

797 19 796 4

795 20 797 5

789 21 795 6

788 22 795 7

793 23 795 8

525 24 795 9

0 25 796 10 0

26 796 11 0

27 797 12 0

28 796 13 0

29 796 14 0

30 796 15 38 31 791 16 736 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.

MONTH:

January, 1995 Day 1

2 3

4 5

6 7

8 9

10 11 12 13 14 15 16 INSTRUCTIONS e

Surry Monthly Operating Report No. 95-01 Page 8 of 19 AVERAGE DAILY UNIT POWER LEVEL Docket No.: 50-281 Unit Name:

Surry Unit 2 Date:

02-04-95 Completed by:

Pat Kessler Telephone: 365-2790 Average Daily Power Level Average Daily Power Level (MWe-Net)

Day (MWe-Net) 788 17 747 787 18 740 785 19 737 785 20 730 788 21 723 788 22 710 789 23 705 788 24 701 787 25 696 786 26 692 780 27 686 773 28 681 768 29 678 763 30 670 759 31 673 753 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. 95-01 Page 9 of 19

SUMMARY

OF OPERATING EXPERIENCE MONTH/YEAR: January, 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.

UNJTONE:

01/01/95 01/08/95 01/14/95 01/15/95 01/16/95 01/31/95 UN1rTwo:

01/01/95 01/11/95 01/31/95 0000 1554 1559 2048 0608 2400 The reporting period began with the unit operating at 100% power, 825 MWe.

Reactor tripped when Main Feedwater Pump l-FW-P-1 B tripped due to low lube oil pressure to motor bearing, resulting from failed lube oil pipe coupling.

Reactor critical.

Generator on line. Started power increase.

Stopped power increase at 100%, 825 MWe.

The reporting period ended with the unit operating at 100% power, 825 MWe.

0000 The reporting period began with the unit operating at 100% power, 825 MWe.

0330 Began power coastdown.

2400 The reporting period ended with the unit operating at 85% power, 703 MWe in a power coastdown.

SE 95-002 TM S2-94-17 DCP 90-009 DCP 90-010 Surry Monthly Operating Report No. 95-01 Page 10 of 19 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR: January, 1995 Safety Evaluation 1-04-95 Safety Evaluation 95-002 assessed the continued operation of Unit 1 with failed reactor

. vessel leak-off temperature detector 1-RC-Tl-1401.

The evaluation concluded that other methods of detecting reactor coolant system (RCS) leakage remain available (e.g., RCS make-up requirements, containment sump level, containment pressure, temperature, and humidity) and satisfy the Technical Specification requirements for RCS leak detection. Therefore, an unreviewed safety question does not exist.

Temporary Modification (Safety Evaluation No.95-003) 01-05-95 Temporary Modification (TM) S2-94-17 installed electrical jumpers to maintain circuit continuity during the replacement of Unit 2 relay 2-RC-RL Y-MUX-2.

The TM did not affect station protection circuits or the function of the reactor coolant make-up control system. Double verification of jumper installation/removal and post-maintenance testing was performed. Therefore, an unreviewed safety question did not exist.

Design Change Package (Safety Evaluation No.90-219) 1-06-95 Design Change Package 90-009 installed an ultrasonic level indication system as a redundant means of monitoring the Unit 1 Reactor Coolant System (RCS) level during mid-loop operation.

The ultrasonic level indication system is completely external to the RCS and does not affect RCS or other system operation. Therefore, an unreviewed safety question does not exist.

Design Change Package (Safety Evaluation No.91-015) 1-06-95 Design Change Package 90-010 installed an ultrasonic level indication system as a redundant means of monitoring the Unit 2 Reactor Coolant System (RCS) level during mid-loop operation.

The ultrasonic level indication system is completely external to the RCS and does not affect RCS or other system operation. Therefore, an unreviewed safety question does not exist.

FS 95-01 AC 81-94-1223 TM S1-95-01 Surry Monthly Operating Report No. 95-01 Page 11 of 19 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR: January, 1995 Updated Final Safety Analysis Report Change (Safety Evaluation No.95-004) 1-06-95 UFSAR Change 95-01 revised Section 6.2.2.2.1, "[Safety Injection System]

Accumulator," to clarify that only one safety injection (SI) accumulator check valve is needed to provide isolation.

This change was administrative in nature and did not involve any physical changes to the plant. The Safety Analysis Report (SAR) analyses were performed based on the SI accumulator check valves being in the open position. The isolation capability of the subject valves was not considered. Therefore, an unreviewed safety question does not exist.

Administrative Control (Safety Evaluation No.95-006) 1-10-95 Administrative control of Unit 1 letdown isolation and pressurizer heater trip automatic functions was established to facilitate the replacement of failed letdown isolation/pressurizer heater trip control relay 1-RP-REL-LC460CX.

A licensed operator was assigned to immediately manually initiate the subject automatic functions in the event pressurizer level decreased to an indicated level of 17%. Manual initiation of these nonsafety-related functions is acceptable since they are not protective functions for the Reactor Protection System or Engineered Safety Features actuation systems. The Technical Specifications margin of safety was not affected by these administrative controls. Therefore, an unreviewed safety question did not exist.

Temporary Modification (Safety Evaluation No.95-005) 1-10-95 Temporary Modification (TM) S1-95-01 installed a replacement resistance temperature device (RTD) in the local temperature indicator thermowell to provide the Unit 1 Steam Generator (SG) "B" inlet feedwater temperature.

The local temperature indicator thermowell is of the same design as the main RTD thermowell, except for length. An evaluation of this difference concluded, based on a comparison of previous temperature data, that a reliable and accurate indication of the SG "B" inlet feedwater temperature can be obtained. This modification did not reduce the Technical Specifications margin of safety. Therefore, an unreviewed safety, question did not exist.

TM S1-95-02 DCP 93-003 TM S2-95-01 SE 95-016 e

e Surry Monthly Operating Report No. 95-01 Page 12 of 19 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR: January, 1995 Temporary Modification (Safety Evaluation No.95-007) 1-11-95 Temporary Modification (TM) S1-95-02 installed an electrical jumper to maintain Unit 1 letdown valve LCV-1460B in the open position during the replacement of failed letdown isolation/pressurizer heater trip control relay 1-RP-REL-LC460CX.

The TM did not affect station protection circuits or th~ isolation function of the redundant letdown valve, LCV-1460A. Double verification of jumper installation/removal and post-maintenance testing was performed. Therefore, an unreviewed safety question did not exist.

Design Change Package (Safety Evaluation No.93-158) 1-12-95 Design Change Package 93-003 installed new redundant indicators on the main control board for the Unit 1 and 2 High Head Safety Injection (HHSI) system flow rates and reconfigured the power supplies to provide redundant sources to the associated instrumentation loops.

These safety-related, seismically installed modifications upgraded the HHSI instrumentation loops to meet the requirements of Regulatory Guide 1.97. Implementation of these modifications did not affect the operation of the safety injection systems or the Technical Specifications margin of safety. Therefore, an unreviewed safety question does not exist.

Temporary Modification (Safety Evaluation No.95-009) 1-17-95 Temporary Modification (TM) S2-95-01 installed electrical jumpers to maintain the Unit 2 Circulating Water (CW) Pump "N upper guide bearing alarm module circuit continuity while the module was removed from the CW pump motor temperature panel to be repaired.

The TM did not affect the other "2/>t CW pump motor temperature thermocouples and alarm functions and did not impose any operational limitations on the subject pump. Double verification of jumper installation/removal and post-maintenance testing was performed.

Therefore, an unreviewed safety question did not exist.

Safety Evaluation 1-31-95 Safety Evaluation 95-016 was performed to evaluate the 1995 Unit 2 refueling outage schedule.

The evaluation concluded that the refueling outage schedule is acceptable based on a review of the planning, procedures, policies, shutdown risk, and monitoring management that are performed for the outage. Therefore, an unreviewed safety question does not exist.

OP-4.52 1 [2]-PT-8.1 1 [2]-PT-8.2 1 [2]-IPT-RP-AFW-001 2-0P-CS-005 e Surry Monthly Operating Report No. 95-01 Page 13 of 19 PROCEDURE OR METHOD OF OPERATION CHANGES THAT DID NOT REQUIRE NRC APPROVAL MoNTHIYEAR: January, 1995 Operating Procedure (Safety Evaluation No. 94-21 OA) 12-07-94 Operating Procedure OP-4.52, "CASTOR X/33 Cask Loading and Handling," was revised to delete the requirement to have the Decontamination Building ventilation aligned to the Auxiliary Ventilation system filtered exhaust.

The Auxiliary Ventilation system filtered exhaust is designed to remove gaseous iodine from designated areas during a loss of coolant or fuel handling accident. The spent fuel loaded in the cask has no significant radioiodines remaining since it has cooled for at least ten years.

Furthermore, operation of the Decontamination Building ventilation aligned to the Auxiliary Ventilation system filtered exhaust is not required by the Safety Analysis Report or Technical Specifications. Therefore, an unreviewed safety question does not exist.

Instrument Periodic Test Procedures (Safety Evaluation No.93-075, Revision 2) 1-13-95 Instrument Periodic Test Procedures 1 [2]-PT-8.1, "Reactor Protection System Logic (for Normal Operations)," and 1[2]-PT-8.2, "Reactor Protection Logic," were revised and Instrument Periodic Test Procedure 1 [2]-IPT-RP-AFW-001, "Under Voltage and Low Low Steam Generator Logic Start of the Steam Driven Auxiliary Feed Pump," was developed to incorporate administrative control steps for the steam generator (SG) blowdown permissive key switches to ensure proper operation of the SG blowdown trip valves.

This change places the SG blowdown permissive key switches under administrative control when in the permissive mode during monthly logic testing. The procedural steps direct an operator to place the key switches in the normal position in the event of an auxiliary feedwater system automatic start signal. This action ensures operability of the SG blowdown trip valves. Therefore, an unreviewed safety question does not exist.

. Operating Procedure (Safety Evaluation No.95-010) 1-20-95 Operating Procedure 2-0P-CS-005, "Purifying Unit 2 RWST," was revised to provide instructions for administratively controlling Condensate System valves 1 [2]-CS-27 when performing the subject procedure Appropriate administrative controls are provided in the procedure to ensure that the subject valves are closed within 90 seconds of the initiation of a safety injection. Closure of the valves within this time limit ensures that sufficient Refueling Water Storage Tank (RWST) inventory is maintained for accident mitigation. Therefore, an unreviewed safety question does not exist.

1 [2]-0P-RL-003 1 [2]-0P-RL-004 1 [2]-0PT-ZZ-001 1 [2]-0PT-ZZ-002 2-0P-RC-004 2-0P-CH-008 CH-93.120 O-DRP-004 e Surry Monthly Operating Report No. 95-01 Page 14 of 19 PROCEDURE OR METHOD OF OPERATION CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR: January, 1995 Operating Procedures (Safety Evaluation No.95-011) 1-24-95 Operating Procedures 1 [2]-0P-RL-003, "Installation and Operation of the POTT to RL System Jumper," and 1[2]-0P-RL-004, "Removal of the PDTI to RL System Jumper," were developed to provide instructions for the installation of a temporary mechanical jumper(s) to connect the Gaseous Drains (DG) System to the Reactor Cavity Purification (RL)

System.

The mechanical jumper(s) will be installed when a unit is shut down in order to conserve primary system inventory and thereby reduce the volume of liquid waste. The jumper(s) and associated connections will be leak tested before being placed in service.

Instructions are also provided to prevent inadvertent Reactor Coolant System dilution and to ensure refueling containment integrity is maintained. Therefore, an unreviewed safety question does not exist.

Operations Periodic Test Procedures (Safety Evaluation No.95-013) 1-26-95 Operations Periodic Test Procedures 1/2-0PT-ZZ-001, "ESF Actuation with Undervoltage and Degraded Voltage - 1 H [2H] Bus" and 1/2-0PT-ZZ-002, "ESF Actuation with Undervoltage and Degraded Voltage - 1 J [2J] Bus" were revised to provide instructions for the installation of electrical jumpers to permit reactor coolant system (RCS) letdown to be initiated, if necessary to maintain pressurizer level, while a safety injection test signal is in place.

The unit will be at cold shutdown when the electrical jumpers are installed. One train of the Safety Injection (SI) system will be tested at a time. The SI train not being tested will remain capable of functioning as designed. Therefore, an unreviewed safety question does not exist.

Operating Procedures Chemistry Procedure Design Requirement Procedure (Safety Evaluation No.92-038) 1-26-95 Operating Procedure 2-0P-RC-004, "Draining the RCS to Reactor Flange Level,"

Operating Procedure 2-0P-CH-008, "Chemical Addition to the RCS," Chemistry Procedure CH-93.120, "Primary Coolant Chemistry Controls: Refueling Outage," and Design Requirement Procedure O-DRP-004, "Precautions, Limitations, and Setpoints," were revised to provide instructions for implementing an alternate hydrogen peroxide addition method for crud burst treatment of the reactor coolant system (RCS).

The new method allows hydrogen peroxide to be injected with the RCS depressurized, the reactor coolant pumps secured, and a residual heat removal pump running.

The procedure requires precautionary measures to be taken to prevent an explosive gas mixture from forming in the RCS. These measures include: 1) pressurizer level required to be between 5% and 50%, 2) verify through sampling that the RCS has been sufficiently degassed, and 3) a nitrogen blanket placed on the volume control tank with* hydrogen isolated. Therefore, an unreviewed safety question does not exist.

2-0P-VS-001 2-0P-18.1.1 2-0P-18.1.2 2-TOP-4060 2-TOP-4061 e Surry Monthly Operating Report No. 95-01 Page 15 of 19 PROCEDURE OR METHOD OF OPERATION CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR: January, 1995 Operating Procedures Temporary Operating Procedures (Safety Evaluation No.95-015) 1-30-95 Operating Procedures 2-0P-VS-001, "Containn,ent Ventilation," 2-0P-18.1.1, "Opening Both Containment Personnel Hatch Doors," and 2-0P-18.1.2, "Closing Both Containment Personnel Hatch Doors," were revised and Temporary Operating Procedures 2-TOP-4060, "Installation of Temporary Flanges and Ventilation Duct Work for Purging Unit 2 Containment with 1-VS-F-59," and 2-TOP-4061, "Removal of Temporary Flanges and Ventilation Duct Work Installed for Purging Unit 2 Containment with 1-VS-F-59," were developed to provide instructions for the installation, operation, and removal of a flexible duct jumper between the Unit 2 containment purge and the nonsafety-related auxiliary building charcoal exhaust filter 1-VS-FL-14.

The subject ventilation alignment protects the safety-related filters from potential contaminants originating from the Unit 2 containment while shutdown and does not impact the ability of the safety-related filters to respond to a Unit 1 safety injection signal.

Containment purge has been aligned to the safety-related filters for the entire duration of previous outages. These procedure changes reflect the requirement for the Unit 2 containment purge to be aligned to the safety-related charcoal exhaust filters during fuel handling operations in the Unit 2 containment. Therefore, an unreviewed safety question does not exist.

e Surry Monthly Operating Report No. 95-01 Page 16 of 19 TESTS AND EXPERIMENTS THAT DID NOT REQUIRE NRC APPROVAL MoNTHIYEAR: January, 1995 None During the Reporting Period

CHEMISTRY REPORT MONTH/YEAR: January, 1995 Unit No. 1 Primarv Coolant Analysis Max.

Min.

Avr;{.

Gross Radioactivity, 1.1Ci/ml 3.55E-1 1.27E-2 2.19E-1 Suspended Solids, ppm

~0.1

~0.1 Gross Tritium 1,1Ci/ml 1.19E-1 4.94E-2 7.67E-2 11 31, 1,1Ci/ml 5.36E-4 3.49E-5*

4.04E-4 1131 ;1133 0.07 0.05 0.06 HydroQen, cc/kQ 40.4 29.3 35.8 Lithium com 2.60 1.48 2.14 Boron - 10, com*

226.4 108.2 150.1 Oxygen, (DO), ppm

<0.005

<0.005 Chloride, ppm

<0.050 0.002 0.006 oH at 25 degree Celsius 7.16 6.52 6.94 Boron - 1 O = Total Boron x 0.196 Comments:

None e Surry Monthly Operating Report No. 95-01 Page 17 of 19 Unit No. 2 Max.

Min.

AVQ.

2.19E-1 7.47E-2 1.71E-1

~0.1

~0.1 7.92E-2 4.13E-2 5.80E-2 1.24E-4 7.51 E-5 9.66E-5 0.09 0.05' 0.07 40.9 32.7 36.9 0.93 0.72 0.79 5.9 0.2 1.2

<0.005

<0.050

<0.001 0.003 10.0 7.78 9.07

r v

New or Spent Fuel Shipment Date Stored or Number Received FUEL HANDLING UNITS 1 & 2 MONTH/YEAR: January, 1995 Number of Assemblies per Shipment Assembly Number ANSI Number e Surry Monthly Operating Report No. 95-01 Page 18 of 19 Initial Enrichment New or Spent Fuel Shipping Cask Activity No Fuel Received or Stored During the Reporting Period

e e Surry Monthly Operating Report No. 95-01 Page 19 of 19 DESCRIPTION OF PERIODIC TEST(S) WHICH WERE NOT COMPLETED WITHIN THE TIME LIMITS SPECIFIED IN TECHNICAL SPECIFICATIONS MONTH/YEAR: January, 1995 None During the Reporting Period

ML18153B236

Text

SUMMARY

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