ML18153A555
| ML18153A555 | |
| Person / Time | |
|---|---|
| Site: | Surry  |
| 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) | |
Text
t_/
VIRGINIA. ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 December 12, 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.95-628 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 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
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- VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION MONTHLY OPERATING REPORT REPORT No. 95-11 Approved: 1 011-----/ l...- /I~ 9S-Station Manager Date
TABLE OF CONTENTS Section
.urry Monthly Operating Report No. 95-11 Page 2 of 20 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.:
Date:
Completed By:
50-280 12-04-95 D. Mason 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 November, 1995 2546 847.5 788 840 801 Telephone:
(804) 365-2459
- 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.:
Date:
Completed By:
50-281 12-04-95 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 November, 1995 2546 847.5 788 840 801
- 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 INITIAL CRITICALITY ACHIEVED INITIAL ELECTRICITY COMMERCIAL OPERATION
,A."
.urry Monthly Operating Report No. 95-11 Page 5 of 20 UNIT SHUTDOWN AND POWER REDUCTION
{EQUAL To OR GREATER THAN 20%}
REPORT MONTH: November, 1995 (1}
(2}
(3}
(4}
(5}
Method.
Docket No.:
50-280 Unit Name:
Surry Unit 1 Date:
12-04-95 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 (1}
F:
Forced S: Scheduled (4)
(2}
REASON:
Down Rx 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 (NUREG 0161)
(3)
METHOD:
1 -
Manual 2 -
Manual Scram.
3 -
Automatic Scram.
4 -
Other (Explain)
(5)
Exhibit 1 - Same Source.
(1)
I
.urry Monthly Operating Report No. 95-11 Page 6 of 20 UNIT SHUTDOWN AND POWER REDUCTION (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 (2)
(3)
(4)
(5)
Method Duration of LER No.
System Component Cause & Corrective Action to Date Type Hours Reason Shutting Code Code Prevent Recurrence 11/07/95 F
356.7 (1)
F:
Forced S:
Scheduled Down Rx A
3 i
'12-95-007 I
(2)
I REASON:
1 A -
Equipment Failure (Explain)
B -
Maintenance or Test C -
Refueling D -
Regulatory Restriction AB E -
Operator Training & Licensing Examination F -
Administrative G
Operational Error (E1plain)
(4)
\\
Exhibit G - Instructions for Preparation of Data Entry S,heets for Licensee Event Report (LER) File (NU REG 0161)
I p
Loss of Coolant Loop Flow due to instantaneous ground on 2-RC-P-1 C (3)
METHOD:
1 -
Manual 2 -
Manual Scram.
3 -
Automatic Scram.
4 -
Other (Explain)
(5)
Exhibit 1 - Same Source.
AVERAGE DAILY UNIT POWER I
MONTH:
November, 1995 Average Daily Power Level Day (MWe-Net)
Day 1
824 17 2
823 18 3
823 19 4
822 20 5
823 21 6
822 22 7
818 23 8
813 24 9
812 25 10 815 26 11 821 27 12 819 28 13 818 29 14 818 30 15 817 16 822 INSTRUCTIONS I
.Surry Monthly Operating Report No. 95-11 Page 7 of 20 LEVEL Docket No.: 50-280 Unit Name:
Surry Unit 1 Date: 12-06-95 Completed by:
John D. Kilmer Telephone: (804) 365-2792 Average Daily Power Level (MWe-Net) 820 820 812 813 821 822 824 825 825 824 824 821 822 822 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. 95-11 Page 8 of 20 AVERAGE DAILY UNIT POWER LEVEL MONTH:
November, 1995 Average Daily Power Level Day 2
3 4
5 6
7 8
9 10 11 12 13 14 15 16 INSTRUCTIONS (MWe-Net) 820 817 819 819 822 821 332 0
0 0
0 0
0 0
0 0
Day 17 18 19 20 21 22 23 24 25 26 27 28 29 30 Docket No.: 50-281 Unit Name:
Surry Unit 2 Date: 12-06-95 Completed by:
John D. Kilmer Telephone: (804) 365-2792 Average Daily Power Level (MWe - Net) 0 0
0 0
0 343 811 824 823 823 824 825 821 824 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 11/30/95 UNIT Two:
11/01/95 11/07/95 11/22/95 11/23/95 11/30/95 0000 2400 0000 0959 0005 0637 0446 2400 The reporting period began with the unit operating at 100% power, 853 Mwe.
The reporting period ends with the unit operating at 100% power, 853 Mwe The reporting period began with the unit operating at 100% power, 855 Mwe.
Automatic Reactor trip on loss of 2-RC-P-1 C (instantaneous ground)
Reactor critical following repairs to 2-RC-P-1C Unit on-line, commence power escalation to full power Unit at full power, 855 Mwe The reporting period ends with the unit operating at 100% power, 850 Mwe
Ii O-TOP-4068 O-TOP-4069 TM S1-95-06 O-ECM-1426-01
.Surry Monthly Operating Report No. 95-11 Page 10 of 20 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 Temporary Operating Procedures (Safety Evaluation No.95-163) 11-07-95 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.
Temporary Modification (Safety Evaluation No.95-164) 11-08-95 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.
PAR to O-ECM-1426-01 (Safety Evaluation 95-165) 11-08-95 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.
TM S2-95-15 TM S2-95-16 TM S2-95-15 TM S2-95-16 DCP 95-038 DCP 93-004-3 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MoNTHNEAR: November, 1995 Temporary Modification (Safety Evaluation No.95-166)
-urry Monthly Operating Report No. 95-11 Page 11 of 20 11-10-95 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.
Temporary Modification 11-10-95 (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.
Design Change Package (Safety Evaluation No.95-167) 11-10-95 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.
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.
JCO S1-95-003 JCO S1-95-004 TM S2-95-17 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 Justification for Continued Operation (Safety Evaluation 95-170)
.urry Monthly Operating Report No. 95-11 Page 12 of 20 11-15-95 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.
Justification for Continued Operation (Safety Evaluation 95-172) 11-17-95 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.
Temporary Modification (Safety Evaluation No.95-173 11-18-95 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.
FS 95-17 FS 95-17 1-0P-BC-001 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 UFSAR Change Request (Safety Evaluation No.95-174) lturry Monthly Operating Report No. 95-11 Page 13 of 20 11/21/95 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.
UFSAR Change Request (Safety Evaluation No.95-175) 11 /21/95 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.
Temporary Modification (Safety Evaluation No.95-177) 11/28/95 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 TM 81-95-006 FACILITY CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTH/YEAR: November, 1995 Temporary Modification (Safety Evaluation No.95-066 Rev 1)
.urry Monthly Operating Report No. 95-11 Page 14 of 20 11-30-95 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.
QA Topical Report 1/2-GP-2.1 1/2-0P-TM-001 1/2-0P-TM-004 1/2-0P-19.4
.urry Monthly Operating Report No. 95-11 Page 15 of 20 PROCEDURE OR METHOD OF OPERATION CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 Operational Quality Assurance Program Topical Report (Safety Evaluation No.95-160) 11-1-95 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.
General Operating Procedure Operating Procedure (Safety Evaluation No.95-161) 11-2-95 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.
Operating Procedure (Safety Evaluation No.95-168) 11-14-95 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.
Appendix R Report
.urry Monthly Operating Report No. 95-11 Page 16 of 20 PROCEDURE OR METHOD OF OPERATION CHANGES THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 1 o CFR 50, Appendix R Report (Safety Eyaluation 95-176) 11-28-95 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.
.urry Monthly Operating Report No. 95-11 Page 17 of 20 TESTS AND EXPERIMENTS THAT DID NOT REQUIRE NRC APPROVAL MONTHNEAR: November, 1995 None During the Reporting Period
. l CHEMISTRY REPORT MONTHNEAR: November, 1995 Unit No. 1 Primarv Coolant Analvsis Max.
Min.
AVQ.
Gross Radioactivity, uCi/ml 5.31 E-1 2.01 E-1 3.22E-1 Suspended Solids, ppm 50.010
225.2 217.0 220.4 Oxygen, (DO), ppm 50.005
None
-urry Monthly Operating Report No. 95-11 Page 18 of 20 Unit No. 2 Max.
Min.
AVQ.
1.96E-1 4.66E-3 1.41E-1 0.175 50.010 0.095 3.53E-1 6.75E-2 2.10E-1 3.49E-4 9.33E-5 1.54E-4 0.11 0.06 0.08 39.0 1.5 15.9 2.32 0.08 1.44 276.2 126.8 217.1 10.0
- 0.005 0.592 0.004
<0.001 0.003 6.96 5.45 6.42
New or Spent Fuel Shipment Date Stored or Number Received New Fuel Shipment or Date Stored or Cask Number Received CASTOR V/21 11/14/95 500.11-026 FUEL HANDLING UNITS 1 & 2 MONTHNEAR: November, 1995 Number of Assemblies Assembly ANSI eer Shiement Number Number Number of Assemblies Assembly per Shipment Number ANSI Number 21 047 LM0077 R03 LMOOTQ 4N9 LM06EN 034 LM0081 J09 LM034M T02 LM02JG T23 LMOOVU R02 LMOOTS S20 LMOOVC R39 LMOOVO R13 LMOOTY OL9 LM06FQ R45 LMOOVW 017 LM0087 J42 LM035E ROS LMOOUO OL3 LM06FS 1R3 LMOC1U G14 LM01QH R52 LMOOVS S16 LMOOUW
.urry Monthly Operating Report No. 95-11 Page 19 of 20 New or Spent Initial Fuel Shipping Enrichment Cask Activitl'.
New or Spent Initial Fuel Shipping Enrichment Cask Activity 3.325 3.097 3.406 3.325 2.902 3.110 3.097 3.097 2.606 3.097 3.097 3.126 3.097 3.325 2.902 3.097 3.126 3.579 2.111 3.097 2.606
-~-
I~
.} r 4lturry Monthly Operating Report No. 95-11 Page 20 of 20 DESCRIPTION OF PERIODIC TEST{S) WHICH WERE NOT COMPLETED WITHIN THE TIME LIMITS SPECIFIED IN TECHNICAL SPECIFICATIONS MONTHNEAR: November, 1995 None During the Reporting Period