ML18153A555

From kanterella
Jump to navigation Jump to search
Monthly Operating Repts for Nov 1995 for Surry Power Units 1 & 2.W/951212 Ltr
ML18153A555
Person / Time
Site: Surry  Dominion icon.png
Issue date: 11/30/1995
From: Mason D, Olsen C, Saunders R
VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.)
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
95-628, NUDOCS 9512180293
Download: ML18153A555 (21)
v • d • e


Text

t_/

VIRGINIA. ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 December 12, 1995 United States Nuclear Regulatory Commission Serial No.95-628 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 November 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

  • r ~ r

.l ~.) \,' .£.

  • i; s,: r::.-;!

,! .,; ~vl 9512180293- 95-1130___

~. ~D~. . _ ADOCK 050~~B~O

_*-,~.,~, .. *- *--~ _. ___ /

( ..

  • VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION MONTHLY OPERATING REPORT REPORT No. 95-11 Approved:

1 011-----/

Station Manager l...-

Date

/I~ 9S-

  • TABLE OF CONTENTS

.urry Monthly Operating Report No. 95-11 Page 2 of 20 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 NRC Approval ............................................................................... 10 Procedure or Method of Operation Changes That Did Not Require NRC Approval ........................................... 15 Tests and Experiments That Did Not Require NRC 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

  • OPERATING DATA REPORT

.urry Monthly Operating Report No. 95-11 Page 3 of 20 Docket No.: 50-280 Date: 12-04-95 Completed By: D. Mason Telephone: (804) 365-2459 1 . Unit Name: .................................................. . Surry Unit 1

2. Reporting Period: ......................................... .. November, 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:

Licensed Thermal Power (MWt) was increased from 2441 to 2546, Maximum Dependable Capacity (Gross MWe) was increased from 820 to 840, and Maximum Dependable Capacity (Net MWe) was increased from 781 to 801 based on the 1mplementat1on of Amendment 203 to Facility Operating License DPA-32, which was issued August 3, 1995. Amendment 203 revised the Fac1hty Operatmg License to pem11t operation at steady state reactor core power levels not m excess of 2546 megawatts {thermal).

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 .......................... 720.0 8016.0 201096.0
12. Number of Hours Reactor Was Critical .......... 720.0 6837.0 137306.7
13. Reactor Reserve Shutdown Hours ............... 0 0 3774.5
14. Hours Generator On-Line ........................... 720.0 6762.0 135003.0
15. Unit Reserve Shutdown Hours ..................... 0 0 3736.2
16. Gross Thermal Energy Generated (MWH) ...... 1832814.5 16087224.9 314540964.1
17. Gross Electrical Energy Generated (MWH) .... 610620.0 5342370.0 102956203.0
18. Net Electrical Energy Generated (MWH) ........ 590471.0 5144983.0 97854006.0
19. Unit Service Factor ................................... 100.0% 84.4% 67.1%
20. Unit Availability Factor. .............................. 100.0% 84.4% 69.0%
21. Unit Capacity Factor (Using MDC Net) ........... 102.4% 82.0% 62.7%
22. Unit Capacity Factor (Using DER Net) ........... 104.1% 81.5% 61.8%
23. Unit Forced Outage Rate ............................ 0.0% 3.1% 16.1%
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

. .. JO

  • OPERATING DATA REPORT

.urry Monthly Operating Report No. 95-11 Page 4 of 20 Docket No.: 50-281 Date: 12-04-95 Completed By: D. Mason Telephone: (804) 365-2459

1. Unit Name: .................................................. . Surry Unit 2
2. Reporting Period: ......................................... . November, 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 .......................... 720.0 8013.0 197976.0
12. Number of Hours Reactor Was Critical .......... 369.8 6421.4 134758.9
13. Reactor Reserve Shutdown Hours ............... 0.0 0.0 328.1
14. Hours Generator On-Line ........................... 363.3 6345.0 132812.1
15. Unit Reserve Shutdown Hours ..................... 0.0 0.0 0.0
16. Gross Thermal Energy Generated (MWH) ...... 905133.1 15374259.9 310642724.2
17. Gross Electrical Energy Generated (MWH) .... 301385.0 5083645.0 101525939.0
18. Net Electrical Energy Generated (MWH) ........ 292370.0 4907135.0 96500171.0
19. Unit Service Factor ................................... 50.5% 79.2% 67.1%
20. Unit Availability Factor ............................... 50.5% 79.2% 67.1%
21. Unit Capacity Factor (Using MDC Net) ........... 50.7% 77.8% 62.5%
22. Unit Capacity Factor (Using DER Net) ........... 51.5% 77.7% 61.9%
23. Unit Forced Outage Rate ............................ 49.5% 8.2% 13.1%
24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):

Refueling Outage, May 2, 1995, 37days

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

  • ,A."

UNIT SHUTDOWN AND POWER REDUCTION

.urry Monthly Operating Report No. 95-11 Page 5 of 20

{EQUAL To OR GREATER THAN 20%}

REPORT MONTH: November, 1995 Docket No.: 50-280 Unit Name: Surry Unit 1 Date: 12-04-95 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)

  • I UNIT SHUTDOWN AND POWER REDUCTION

. u r r y Monthly Operating Report No. 95-11 Page 6 of 20 (EQUAL "J:O OR GREATER THAN 20%)

I REPORT1MONTH: November, 1995 I

Docket No.: 50-281 Unit Name: Surry Unit 2 Date: 12-04-95 Completed by: Craig Olsen Telephone: (804) 365-2155 (1) (2) (3) (4) (5)

Method Duration of LER No. System Component Cause & Corrective Action to Date Type Hours Reason Shutting Code Code Prevent Recurrence Down Rx i

11/07/95 F 356.7 A 3 '12-95-007 AB p Loss of Coolant Loop Flow I

due to instantaneous ground on 2-RC-P-1 C (1) (2) I (3)

F: Forced REASON: 1 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 (E1plain)

(4) \ (5)

Exhibit G - Instructions for Preparation of Data Entry S,heets Exhibit 1 - Same Source.

for Licensee Event Report (LER) File (NU REG 0161) I

... .. .Surry Monthly Operating Report No. 95-11 Page 7 of 20 AVERAGE DAILY UNIT POWER LEVEL I

Docket No.: 50-280 Unit Name: Surry Unit 1 Date: 12-06-95 Completed by: John D. Kilmer Telephone: (804) 365-2792 MONTH: November, 1995 Average Daily Power Level Average Daily Power Level Day (MWe- Net) Day (MWe- Net) 1 824 17 820 2 823 18 820 3 823 19 812 4 822 20 813 5 823 21 821 6 822 22 822 7 818 23 824 8 813 24 825 9 812 25 825 10 815 26 824 11 821 27 824 12 819 28 821 13 818 29 822 14 818 30 822 15 817 16 822 INSTRUCTIONS I

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.

  • AVERAGE DAILY UNIT POWER LEVEL

.Surry Monthly Operating Report No. 95-11 Page 8 of 20 Docket No.: 50-281 Unit Name: Surry Unit 2 Date: 12-06-95 Completed by: John D. Kilmer Telephone: (804) 365-2792 MONTH: November, 1995 Average Daily Power Level Average Daily Power Level Day (MWe- Net) Day (MWe - Net) 820 17 0 2 817 18 0 3 819 19 0 4 819 20 0 5 822 21 0 6 821 22 343 7 332 23 811 8 0 24 824 9 0 25 823 10 0 26 823 11 0 27 824 12 0 28 825 13 0 29 821 14 0 30 824 15 0 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.

'I.. * ..

  • -urry Monthly Operating Report No. 95-11 Page 9 of 20

SUMMARY

OF OPERATING EXPERIENCE MONTHNEAR: November, 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.

UNIT ONE:

11/01/95 0000 The reporting period began with the unit operating at 100% power, 853 Mwe.

11/30/95 2400 The reporting period ends with the unit operating at 100% power, 853 Mwe UNIT Two:

11/01/95 0000 The reporting period began with the unit operating at 100% power, 855 Mwe.

11/07/95 0959 Automatic Reactor trip on loss of 2-RC-P-1 C (instantaneous ground) 11/22/95 0005 Reactor critical following repairs to 2-RC-P-1C 0637 Unit on-line, commence power escalation to full power 11/23/95 0446 Unit at full power, 855 Mwe 11/30/95 2400 The reporting period ends with the unit operating at 100% power, 850 Mwe

Ii

  • FACILITY CHANGES THAT DID NOT

.Surry Monthly Operating Report No. 95-11 Page 10 of 20 REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 O-TOP-4068 Temporary Operating Procedures 11-07-95 O-TOP-4069 (Safety Evaluation No.95-163)

A mechanical jumper is installed between containment purge and auxiliary building general exhaust filter 1-VS-FL-14. The jumper is installed to minimize the refueling impact on safety related filters by allowing containment purge to flow through a nonsafety charcoal filter except when fuel is being handled inside containment.

This lineup does not impact the ability of the safety-related filters to respond to a Unit's safety injection signal. Additionally, any gasses released by a failed jumper would remain within the Auxiliary Building and be monitored prior to release. Therefore, an unreviewed safety question does not exist.

TM S1-95-06 Temporary Modification 11-08-95 (Safety Evaluation No.95-164)

Temporary Modification (TM) S1-95-06 installed and removed electrical jumpers which maintained the Unit 1 Circulating Water (CW) Pump "C" 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 "2A" 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.

O-ECM-1426-01 PAR to O-ECM-1426-01 11-08-95 (Safety Evaluation 95-165)

Safety Evaluation 95-165 assessed the installation of jumpers to bypass the RHR inlet MOV torque switch to allow operation of the valve from the main control room as necessary. This valve is a normally closed de-energized valve in series with 2-RH-MOV-2700 to provide isolation from the 'A' Loop Hot Leg. The operation of 2-RH-MOV-2701 is enabled on decreasing RCS pressure sensed by a pressure transmitter.

A jumper was installed to allow operation and testing of 2-RH-MOV-2701 during unit shutdown with a known problem on the MOV torque switch contacts. No other limit switches were affected by this activity. The postulated malfunction for this valve is failure to open. Neither the capability of this valve to open, nor the pressure interlock which prevents the opening of this valve will be affected. The capability of the RHR system to perform its function is likewise not affected. Therefore, the reliable operation of the valve has been maintained, and an unreviewed safety question does not exist.

    • FACILITY CHANGES THAT DID NOT

-urry Monthly Operating Report No. 95-11 Page 11 of 20 REQUIRE NRC APPROVAL MoNTHNEAR: November, 1995 TM S2-95-15 Temporary Modification 11-10-95 TM S2-95-16 (Safety Evaluation No.95-166)

A temporary blocking device was installed in 2-RC-PCV-2455C and 2-RC-PCV-2456.

Installation of this blocking device allowed a vent path to exist in the RCS in accordance with 2-0SP-ZZ-004 during disassembly of the PORV's. This was required since the normal method is to install a blocking device under a Tagging Order. Since the valve was disassembled, a tagging order could not be used.

Since the unit was at cold shutdown, no safety concerns exist. Therefore, the accident analysis assumptions are unaffected, the margin of safety is not decreased and an unreviewed safety question does not exist.

TM S2-95-15 Temporary Modification 11-10-95 TM S2-95-16 (Safety Evaluation No.95-166 rev 1)

Same as above except that a temporary blocking device was installed in 2-RC-PCV-2455C OR 2-RC-PCV-2456 versus both valves.

DCP 95-038 Design Change Package 11-10-95 (Safety Evaluation No.95-167)

The DCP was designed to gather data during the performance of 2-ST-0317. This data was used to determine what actions will be implemented to provide a more accurate indication of the position of rod M-10.

An unreviewed safety question will not be created by this design change because it will modify the circuit that monitors the rod position and will not affect the ability to insert the control rod(s) into the core.

DCP 93-004-3 Design Change Package 11/14/95 (Safety Evaluation No. 93-0047, Rev1)

Design Change Package (DCP) 93-004-3 replaced non-environmentally qualified Fisher &

Porter transmitters with environmentally qualified Rosemount transmitters for the recirculation spray system. These new transmitters operate within the previously established design parameters. No new failure modes exist, since this is a replacement of existing equipment with equal or better than existing equipment. Therefore there are no unreviewed safety questions.

  • FACILITY CHANGES THAT DID NOT

. u r r y Monthly Operating Report No. 95-11 Page 12 of 20 REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 JCO S1-95-003 Justification for Continued Operation 11-15-95 (Safety Evaluation 95-170)

The unit 1 source range detectors are continuing to spike and are behaving erratically.

The source range detectors have been returned to degraded but operable status. A Justification for Continued Operation has been issued which contains compensatory actions regarding continued operation in a degraded condition.

The compensatory actions provide the necessary guidance to prevent or limit a reactivity insertion transient with operable but degraded source range detectors. Therefore there are no unreviewed safety questions.

JCO S1-95-004 Justification for Continued Operation 11-17-95 (Safety Evaluation 95-172)

A weld connection on the unit 2 "A" steam generator located at the channel head boss connection failed. The preliminary identified cause was transgrannular stress corrosion cracking. Because similar configurations exist on the other unit 1 S/Gs, the potential for another similar failure exists.

JCO S1-95-004 requires the channel head drain area of all three S/G's for unit 1 to be monitored for any sign of leakage during the unit's routine monthly containment entry.

Routine leakage monitoring in accordance with 1-0PT-RC-10.0 will continue along with use of OC-52 if increased leakage is noted.

Plant safety systems and the failure mechanism provide adequate assurance that the potential RCS leakage paths at the S/G channel head lines will not pose an unreviewed safety question.

TM S2-95-17 Temporary Modification 11-18-95 (Safety Evaluation No.95-173 Temporary Modification (TM) S2-95-17 installed electrical jumpers to maintain power to downstream to relay 74A, which is an alarm relay used for testing the feedwater isolation circuits, and relay F1-YA which blocks the opening of the feedwater regulation valve while the reactor trip breakers are open during the replacement of relay 2-SI-RL Y-RTA.

The activity was performed while Unit 2 was at cold shutdown when the SI system was blocked. Double verification of jumper installation/removal was performed. Therefore, an unreviewed safety question does not exist.

lturry Monthly Operating Report No. 95-11 Page 13 of 20 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 FS 95-17 UFSAR Change Request 11/21/95 (Safety Evaluation No.95-174)

The existing 3,000 HP main feedwater pump motors on Unit 2 are being replaced with new 3,500 HP motors. The DCP will initially change only the tandem pair of motors on the "A" pump, but it is anticipated that the motors on the "B" pump will also be changed by a field change to the DCP.

There is no impact on the margin of safety as the motors themselves are not directly responsible for any safety-related function and the motor size is not mentioned in the Technical Specifications. The motors are taken out of service by an accident (SI) signal.

The only impact on plant performance of the new motors will be an increased reliability of the main feedwater pumps.

For these reasons, an unreviewed safety question does not exist relative to the design change.

FS 95-17 UFSAR Change Request 11 /21/95 (Safety Evaluation No.95-175)

The existing 3,000 HP main feedwater pump motors on Unit 1 are being replaced with new 3,500 HP motors. The DCP will initially change only the tandem pair of motors on the "B" pump, but it is anticipated that the motors on the "A" pump will also be changed by a field change to the DCP.

There is no impact on the margin of safety as the motors themselves are not directly responsible for any safety-related function and the motor size is not mentioned in the Technical Specifications. The motors are taken out of service by an accident (SI) signal.

The only impact on plant performance of the new motors will be an increased reliability of the main feedwater pumps.

For these reasons, an unreviewed safety question does not exist relative to the design change.

1-0P-BC-001 Temporary Modification 11/28/95 (Safety Evaluation No.95-177)

Procedure 1-0P-BC-001 has been revised to include the installation of a temporary piping jumper. This jumper connects the domestic water system to the central chilled water system to supply make-up water while the bearing cooling water system is out-of-service for maintenance.

The central chillers will remain operable during the installation of this temporary modification. A backflow preventor is installed to prevent the backflow of the chiller system into the domestic water system. This backflow preventor has been verified by Engineering as adequate for the application and will be tested monthly to ensure proper operation.

The cross-connect capability between the central chillers and the MGR/Relay room chillers will not be affected by the installation of the temporary modification. This temporary modification will not affect any safety related system. Therefore, an unreviewed safety question does not exist.

  • ,~... t
  • FACILITY CHANGES THAT DID NOT

. u r r y Monthly Operating Report No. 95-11 Page 14 of 20 REQUIRE NRC APPROVAL MONTH/YEAR: November, 1995 TM 81-95-006 Temporary Modification 11-30-95 (Safety Evaluation No.95-066 Rev 1)

Buried fish spray (FS) piping at the low level requires replacement. A four inch flexible hose will be used to temporarily route the pump discharge to a strainer inlet. This TM will be performed on any or all of the four FS pumps. Additionally, check valve 1-FS-75 will have its internals removed to ensure unit 2 FS will supply cooling water to the low level vacuum priming heat exchangers.

The FS system provides traveling water screen spray wash, circulating water (CW) pump bearing flush, and CW pump motor oil cooling for two of eight CW pump motors. The FS system is non safety related. A loss of FS system pressure will not prevent CW pump operation.

As this temporary modification is on a non safety related system and will not adversely impact equipment important to safety, an unreviewed safety question is not created.

PROCEDURE OR METHOD OF OPERATION CHANGES

. u r r y Monthly Operating Report No. 95-11 Page 15 of 20 THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 QA Topical Report Operational Quality Assurance Program Topical Report 11-1-95 (Safety Evaluation No.95-160)

The Operational Quality Assurance Program Topical Report was revised to reflect the reorganization of the Nuclear organization. Specifically, the Quality Assurance Department has been eliminated and replaced by Nuclear Oversight, certain corporate positions have been consolidated, and quality control inspections and assessments have been relegated to the line organization.

The Operational Quality Assurance Program change reflects a change in management philosophy for addressing safety significant issues associated with the operations phase of the nuclear facilities. The philosophy change and restructuring of independent oversight and quality assurance line functions do not reduce the effectiveness of the Operational QA Program. Therefore, no margin of safety is impacted by this change.

1/2-GP-2.1 General Operating Procedure 11-2-95 1/2-0P-TM-001 Operating Procedure 1/2-0P-TM-004 (Safety Evaluation No.95-161)

The listed procedures were changed to allow for a controlled startup or cooldown of the moisture separator reheaters (MSR) during a unit shutdown by providing remote throttling of the MSR inlet MOVs and first point extraction steam (ES) MOV. This change will provide more guidance and control over the removal and reinstallation of seal-in contacts.

The process of temporarily removing the seal-in contacts from these MOVs has been performed many times in the past. This was accomplished by using Electrical Maintenance Procedure ECM-1504 (MOV Seal-In Removal and Installation). The only difference will be that this task will be controlled by Operating Procedures 1/2 GOP-2.1, 1&2 OP-TM-001 and 1&2-0P-TM-004 which provides more guidance than the ECM. The temporary modifications will be installed and removed by procedure and will be independently verified. Therefore, an unreviewed safety question does not exist.

1/2-0P-19.4 Operating Procedure 11-14-95 (Safety Evaluation No.95-168)

When containment pressure requires an adjustment it is accomplished by bleeding air from the auxiliary building to the containment through manual valves 1-DA-68 or 2-DA-63.

These valves are the isolation valves for the High Radiation Sampling System containment return lines. If an accident occurred during the time a valve was open it would result in a spill into the auxiliary building. The change to the procedure establishes administrative control on the manual valve used to raise containment pressure.

The administrative control will ensure the HRSS integrity is not compromised if an accident occurs while the procedure is in progress. Therefore, an unreviewed safety question does not exist.

PROCEDURE OR METHOD OF OPERATION CHANGES

. u r r y Monthly Operating Report No. 95-11 Page 16 of 20 THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 Appendix R Report 1 o CFR 50, Appendix R Report 11-28-95 (Safety Eyaluation 95-176)

The change to the 10 CFR 50, Appendix R Report includes a revision of the assumption of loss of offsite power for any station fire, the removal of Engineering Evaluation 23, revision of Engineering Evaluation 22, and the update of tables 3-1 and 3-2. A note has been added to exemption 1 discussing an addendum that is pending NRC approval.

Additionally, other changes are being incorporated into the Appendix R Report, such as DCPs that were previously evaluated.

This update does not create any condition not previously analyzed because it is simply documenting commitments, and is consistent with information in the current UFSAR and VPAP 2401, Fire Protection Program. The level of fire protection for the station is not being diminished, and the change will not adversely affect the capacity to achieve and maintain safe shutdown in the event of a fire. Therefore, an unreviewed safety question does not exist.

  • . u r r y Monthly Operating Report TESTS AND EXPERIMENTS THAT DID NOT REQUIRE NRC APPROVAL No. 95-11 Page 17 of 20 MONTHNEAR: November, 1995 None During the Reporting Period

.l

  • -urry Monthly Operating Report No. 95-11 Page 18 of 20 CHEMISTRY REPORT MONTHNEAR: November, 1995 Unit No. 1 Unit No. 2 Primarv Coolant Analvsis Max. Min. AVQ. Max. Min. AVQ.

Gross Radioactivity, uCi/ml 5.31 E-1 2.01 E-1 3.22E-1 1.96E-1 4.66E-3 1.41E-1 Suspended Solids, ppm 50.010  ::;0.010 50.010 0.175 50.010 0.095 Gross Tritium, uCi/ml 3.44E-1 1.64E-1 2.58E-1 3.53E-1 6.75E-2 2.10E-1 1131, µCi/ml 2.23E-2 2.53E-4 3.45E-3 3.49E-4 9.33E-5 1.54E-4 113111133 0.57 0.06 0.17 0.11 0.06 0.08 Hvdrooen, cc/ko 41.4 33.7 37.5 39.0 1.5 15.9 Lithium, ppm 2.33 2.06 2.20 2.32 0.08 1.44 Boron - 10, ppm* 225.2 217.0 220.4 276.2 126.8 217.1 Oxygen, (DO), ppm 50.005  ::;0.005 50.005 10.0  ::;0.005 0.592 Chloride, ppm 0.008 0.005 0.006 0.004 <0.001 0.003 pH at 25 deoree Celsius 7.07 6.12 6.59 6.96 5.45 6.42 Boron - 10 = Total Boron x 0.196 Comments:

None

  • FUEL HANDLING

. u r r y Monthly Operating Report No. 95-11 Page 19 of 20 UNITS 1 & 2 MONTHNEAR: November, 1995 New or Spent Number of New or Spent Fuel Shipment Date Stored or Assemblies Assembly ANSI Initial Fuel Shipping Number Received eer Shiement Number Number Enrichment Cask Activitl'.

New Fuel Number of New or Spent Shipment or Date Stored or Assemblies Assembly Initial Fuel Shipping Cask Number Received per Shipment Number ANSI Number Enrichment Cask Activity CASTOR V/21 11/14/95 21 047 LM0077 3.325 500.11-026 R03 LMOOTQ 3.097 4N9 LM06EN 3.406 034 LM0081 3.325 J09 LM034M 2.902 T02 LM02JG 3.110 T23 LMOOVU 3.097 R02 LMOOTS 3.097 S20 LMOOVC 2.606 R39 LMOOVO 3.097 R13 LMOOTY 3.097 OL9 LM06FQ 3.126 R45 LMOOVW 3.097 017 LM0087 3.325 J42 LM035E 2.902 ROS LMOOUO 3.097 OL3 LM06FS 3.126 1R3 LMOC1U 3.579 G14 LM01QH 2.111 R52 LMOOVS 3.097 S16 LMOOUW 2.606

-~-

I~ :, .} r

  • 4lturry DESCRIPTION OF PERIODIC TEST{S) WHICH WERE NOT COMPLETED Monthly Operating Report No. 95-11 Page 20 of 20 WITHIN THE TIME LIMITS SPECIFIED IN TECHNICAL SPECIFICATIONS MONTHNEAR: November, 1995 None During the Reporting Period
Retrieved from "https://kanterella.com/w/index.php?title=ML18153A555&oldid=2403132"