ML18096A516

Monthly Operating Rept for Jan 1992 for Salem Unit 1.W/ 920213 Ltr

ML18096A516
Person / Time
Site:	Salem
Issue date:	01/31/1992
From:	Shedlock M, Vondra C Public Service Enterprise Group
To:	NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
NUDOCS 9202200100
Download: ML18096A516 (17)

Text

'OPS~*

Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station February 13, 1992 U.S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555

Dear Sir:

MONTHLY OPERATING REPORT SALEM NO. 1 DOCKET NO. 50-272 In compliance with Section 6.9.1.6, Reporting Requirements for the Salem Technical Specifications, the original copy of the monthly operating reports for the month of January 1992 are being sent to you.

Average Daily Unit Power Level Operating Data Report Unit Shutdowns and Power Reductions Safety Related Maintenance 10CFR50.59 Evaluations Operating Summary Refueling Information Sincerely yours,

~~ Salem Operations RH:pc cc: Mr. Thomas T. Martin Regional Administrator USNRC Region I 631 Park Avenue King of Prussia, PA 19046 Enclosures 8-1-7.R4 The Energ}' People 9202200100 920131 ~ 95-2189 (10M) 12-89 PDR ADOCK 05000272 R PDR

AVERAGE DAILY UNIT POWER LEVEL Docket No.: 50-272 Unit Name: Salem #1 Date: 2/10/92 Completed by: Mark Shedlock Telephone: 339-2122 Month January 1992 Day Average Daily Power Level Day Average Daily Power Level (MWe-NET) (MWe-NET) 1 1118 17 1078 2 1118 18 1125 3 1123 19 1125 4 1123 20 1125 5 1118 21 659 6 1118 22 0 7 1115 23 0 8 1115 24 0 9 1127 25 0 10 1108 26 0 11 595 27 266 12 854 28 1017 13 953 29 1119 14 968 30 1124 15 1112 31 1111 16 1112

OPERATING DATA REPORT Docket No: 50-272 Date: 02/10/92 Completed by: Mark Shedlock Telephone: 339-2122 Operating Status

1. Unit Name Salem No. 1 Notes

2. Reporting Period January 1992

3. Licensed Thermal Power (MWt) 3411

4. Nameplate Rating (Gross MWe) 1170

5. Design Electrical Rating (Net MWe) 1115

6. Maximum Dependable Capacity(Gross MWe) 1149

7. Maximum Dependable Capacity (Net MWe) 1106

8. If Changes Occur in Capacity Ratings (items 3 through 7) since Last Report, Give Reason NA 2

9. Power Level to Which Restricted, if any (Net MWe) N/A

10. Reasons for Restrictions, if any NA This Month Year to Date Cumulative

12. Hours in Reporting Period 744 744 127897

12. No. of Hrs. Rx. was Critical 744 744 84344.3

13. Reactor Reserve Shutdown Hrs. 0 0 0

14. Hours Generator On-Line 606.1 606.1 81654.0

15. Unit Reserve Shutdown Hours 0 0 0

16. Gross Thermal Energy Generated (MWH) 2047761. 6 204 7761. 6 257544906.8

17. Gross Elec. Energy Generated (MWH) 664390 664390 85469020

18. Net Elec. Energy Gen. (MWH) 632685 632685 81409258

19. Unit Service Factor 81.5 81.5 63.8

20. Unit Availability Factor 81. 5 81. 5 63.8

21. Unit Capacity Factor (using MDC Net) 76.9 76.9 57.6

22. Unit Capacity Factor (using DER Net) 76.3 76.3 57.1

23. Unit Forced Outage Rate 18.5 18.5 21. 3

24. Shutdowns scheduled over next 6 months (type, date and duration of each)

Refueling outage scheduled to start 4-4-92 and last 67 days.

25. If shutdown at end of Report Period, Estimated Date of Startup:

NA

UNIT SHUTDOWN AND POWER REDUCTIONS REPORT MONTH JANUARY 1992 DOCKET NO. 50-272 UNIT NAME Salem #1 DATE 02/10/92 COMPLETED BY Mark Shedlock .

TELEPHONE 339-2122 METHOD OF SHUTTING LICENSE DURATION DOWN EVENT SYSTEM COMPONENT CAUSE AND CORRECTIVE ACTION 1 2 NO. DATE TYPE (HOURS) REASON REACTOR REPORT # CODE 4 CODE 5 TO PREVENT RECURRENCE 0004 01/11/92 F 19.8 A 5 ------ HH INSTRU #11 AND #12 STEAM GEN. FEED PUMP CONTROLS 0005 01/21/92 F 137.9 A 1 ------ EB xxxxxxx LOSS OF CIRC. WATER PUMP MOTOR POWER 1 2 3 4 5 F: Forced Reason Method: Exhibit G - Instructions Exhibit 1 - Same S: Scheduled A-Equipment Failure (explain) 1-Manual for Preparation of Data Source B-Maintenance or Test 2-Manual Scram Entry Sheets for Licensee C-Refueling 3-Automatic Scram Event Report CLER) File D-Requlatory Restriction 4-Continuation of (NUREG-0161)

E-Operator Training & License Examination Previous outage F-Administrative 5-Load Reduction G-Operational Error (Explain) 9-0ther H-Other (Explain)

• sAFETY R~LATED MAINTENANCE DOCKET NO: 50-272 MONTB: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 WO NO UNIT EQUIPMENT IDENTIFICATION 900810118 1 12 BORIC ACID TRANSFER PUMP FAILURE DESCRIPTION: UPGRADE PUMP - REPLACE POWER FRAME 910828088 1 13 LOOP PRESSURIZER SPRAY TEMPERATURE FAILURE DESCRIPTION: IMPROPER RESPONSE - INVESTIGATE 910930149 1 PASS VALVE 13SS184 FAILURE DESCRIPTION: VALVE EXCEEDED STROKE TIME -

INVESTIGATE 911001183 1 PASS VALVE 13SS182 FAILURE DESCRIPTION: VALVE EXCEEDED STROKE TIME -

INVESTIGATE 920103123 1 VALVE 1SWE28 FAILURE DESCRIPTION: 1SWE28 1/2" PLUGS LEAKING -

REPLACE 920121193 1 VALVE 12MS28 FAILURE DESCRIPTION: NO CLOSED LIGHT INDICATION -

INVESTIGATE 920122073 1 11 STEAM GENERATOR STEAM FLOW CHANNEL I FAILURE DESCRIPTION: STEAM FLOW READING IS OUT OF SPECIFICATION - TROUBLESHOOT 920129104 1 VALVE 15SW58 FAILURE DESCRIPTION: 15SW58 VALVE LEAK - REWORK 920625015 1 16 SERVICE WATER PUMP FAILURE DESCRIPTION: PULL AND REPLACE PUMP WITH SPARE

• 10CFR50.59 EVALUATIONS DOCKET NO: 50-272 MONT~: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 The following items were evaluated in accordance with the provisions of the Code of Federal Regulations 10CFR50.59. The Station Operations Review Committee has reviewed and concurs with these evaluations.

ITEM

SUMMARY

A. Design Change Packages (DCP)

DCP# lEC-3123 Pkg. 1 "Auxiliary Feedwater Tie In of Hydrazine and Ammonia" - This DCP provides a permanent hydrazine and ammonia injection system from the Unit 1 Turbine Building to the 1/2 Auxiliary Feedwater (AF) Pump discharge line. This modification provides a permanent and reliable method for Steam Generator Feedwater Chemistry control with hydrazine and/or ammonia injection during startup and shutdown modes. Installation of this tie in to the AF system will not impact the capability of the AF system to supply an alternate supply of feedwater. The Chemical Feed (CF) injection will only be used during startup and shutdown. During other modes, the manual valves at the AF injection points will be administratively maintained closed to maintain the AF system code boundary. The margin of safety as defined in the Technical Specifications and their bases are not impacted by this modification. (SORC 92-001)

DCP# lEC-3086 Pkg. 1 "Control Room Modifications Phase III" - The purpose of this DCP is to perform modifications to the Unit 1 Control Room. These modifications are being made to implement corrective action to resolve three Human Engineering Discrepancies (HEDs) identified in the Salem Unit 1 Control Room. The HEDs were generated during the Detailed Control Room Design Review conducted in accordance with the requirements of NUREG 0700.

None of the out of service equipment to be removed and the inservice equipment to be relocated serve to mitigate anticipated operational transients, postulated design basis accidents, or other SAR described events.

Further, none of the proposed modifications negatively affect any equipment important to safety. (SORC 92-001)

• 10CFR50.59 EVALUATIONS DOCKET NO: 50-272 MONT~: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd)

ITEM

SUMMARY

DCP# lEC-3081 Pkg. 1 "Salem Unit 1 Condenser Air Removal & Priming System Modification" - This design change will eliminate the need for TMOD 88-012. This TMOD circumvented the Unit 1 interlocking permissive that used to be needed to operate the Condenser Air Removal System. The interlock permissive was originally needed because 11 Vacuum Pump was designed to operate common to both Salem Units.

The installation of 25 Vacuum Pump on Unit 2 eliminated the need for the common use of 11 Vacuum Pump. No programs or procedures will be affected by this DCP. The Unit 1 Condenser Air Removal & Priming System will operate the same after implementation of this DCP as it did before. The Salem Technical Specifications do not address the Condenser Air Removal & Priming System. Therefore, the proposed modification does not reduce the margin of safety for any Technical Specification basis. (SORC 92-003)

DCP# lEC-3053 Pkg. 1 "Penetration Area Service Water Piping Replacement With 6% Moly" This DCP involves the replacement of 10" cement lined carbon steel service water piping with 6% molybdenum stainless steel on elevation 78' in the mechanical piping penetration area. There are a number of major configuration changes which have been incorporated into the new piping hanger design package which will significantly reduce the material and installation costs while enhancing system reliability, maintainability and operability. There is no increase in the probability of occurrence or consequences of an accident previously evaluated in the SAR. There is no introduction of an potential accident of a different type than previously evaluated in the SAR. (SORC 92-007)

DCP# lSC-2256 Pkgs 1-2 "Service Water Piping Replacement - SWIS Bay Nos. 1 & 3" This DCP involves changing out various sections of the existing Service Water piping and valves in the Salem Unit 1 Service

l

• 10CFR50.?9 EVALUATIONS DOCKET NO: 50-272 MON~H: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd)

ITEM

SUMMARY

Water Intake Structure, Bay Nos. 1 & 3 during a refueling outage. The existing piping is primarily cement lined carbon steel piping which is Nuclear Class 3, Seismic Class l, and Piping Schedule 27c. The replacement piping is 6%

molybdenum stainless steel Nuclear Class 3, Seismic Class 1, however, the new Piping Schedule is 27F. The new safety related piping material is compatible for use in the system.

The new stainless steel valves are also Nuclear Class 3, safety related, and compatible for use in the Service Water System. The new safety related piping and valves are designed and installed Seismic Class 1 to assure operability under all required accident conditions. There is no increase in the probability of occurrence or consequences of an accident previously evaluated in the SAR. There is no introduction of an potential accident of a different type than previously evaluated in the SAR.

(SORC 92-007)

DCP# lEC-3054 Pkg. 1 "Containment Fan Coil Unit (CFCU) Service Pipe Replacement" - The purpose of this DCP is to replace the Service Water piping for CFCUs 13, 14 & 15 below elevation 102'with piping made of 6% molybdenum stainless steel. The purpose of this replacement is to significantly increase system reliability and service life. Routing of the new piping is expected to be identical to the existing routing. Due to the change in material, modifications to existing pipe supports and piping support steel were provided as necessary to maintain the Seismic Class 1 integrity of the system. Because the pipe is seismically supported, the potential adverse impact to other safety related equipment is precluded. The new pipe material and installation are designed to be equivalent or better than the pipe it replaces, resulting in significant improvement in system reliability and integrity. The configuration was not changed. Therefore, the system will function identically to that currently installed.

(SORC 92-007)

• 10CFR50.?9 EVALUATIONS DOCKET NO: 50-272 MONrH: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd)

ITEM

SUMMARY

DCP# lEC-3114 Pkgs 1-3 "lA, lB, lC Diesel Generator Jacket Water Vent Lines" - This DCP installs one foot long flex hoses in the jacket water vent lines from the turbochargers to the expansion tanks. The hoses will be located at the 3/8" connection to the turbochargers, replacing the existing hard pipe connections. This will eliminate resonances in the piping from occurring and causing failures at the 3/8" connections. Some hanger modifications will also be performed. All materials to be used meet the pressure and temperature requirements of the Jacket Water (JW) system and is acceptable for use with chromated water. There is no change to the function of the JW system. This DCP will improve the reliability of the JW system and ensure its integrity. A vibration analysis will be performed after the installation of the DCP to ensure that no resonances exist during operation of the D/Gs. A stress analysis has been performed and the proper hanger modifications will be made. There is no change to the operation of the turbochargers or the D/Gs. Therefore, there is no impact to the bases for the Technical Specifications.

(SORC 92-009)

DCP# lEA-1025 "Diesel Generator Load Calculations" - This DCP updates documents impacted by the revised Salem Diesel Generator (D/G) Load Calculation (ES-9.002-0) and confirms the adequacy of the D/Gs. This calculation verifies that the maximum load demand would remain within the manufacturer's ratings which establish the margin of safety for DIG capability. The ability of the D/Gs to support their design load requirements will be demonstrated by periodic testing. Therefore, there is no reduction in the margin of safety associated with this change. ( SORC 92-009)

DCP# lEC-3048 Pkg. 1 "Service Water Pipe Replacement - Unit 1 Room Coolers" - Service Water (SW) pipe will be changed from the existing concrete lined carbon/low alloy steel to 6% molybdenum stainless steel. This encompasses the 11 Room

• 10CFR50.59 EVALUATIONS DOCKET NO: 50-272 MONTH: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd)

ITEM

SUMMARY

Cooler Header supply and return to the Main SW Header. This change will also remove differential pressure controls and control valve 11SW134 from the discharge of the No. 11 Component Cooling Heat Exchanger Pump Room Cooler and replace it with a manual valve. The new configuration will have a static flow balance based on restricting orifices. This DCP does not change the normal or emergency operation of the SW system with the exception of the addition of cross connect capability. The use of the cross connect will be administratively controlled to only those times during which one main header is out of service, increasing the availability of components. The replacement piping is designed to ANSI B31.1, 1967 and fabricated, erected and installed to ANSI B31.7, 1969. There is no reduction in the margin of safety as defined in the bases of the Technical Specifications. ( SORC 92-010)

DCP# lEC-3140 Pkg. 1 "Control Air Piping Modification" - This DCP replaces, reroutes the existing underground Control Air (CA) header on the east side of the Circulating Water Intake Structure (CWIS). The existing underground piping will capped in two places to close the branches. The leaking piping section will be abandoned in place.

Also, this DCP adds valves 1CA1854 through 1CA1858 on the CA header along the east wall of the CWIS for future isolation of CA sections.

The proposed modification affects only the non-safety related section of the CA system which has no impact on the function of the safety related CA. This modification will not affect the mechanical integrity of the CA system since replacement piping and valves meet original design requirements. The section of CA system affected by this modification does not have any safety function. The proposed changes do not alter the original design intent or the modes of operation or function for which the CA system is currently analyzed. Therefore, the margin of safety basis for the Technical Specifications will not be affected.

(SORC 92-010)

• 1ocFR50.59 EVALUATIONS DOCKET NO: 50-272 MONTH: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd)

ITEM

SUMMARY

B. Procedures and Revisions (Proc)

Sl.OP-AB.ROD-0004(Q) "Rod Position Indication Failure" Rev. 0 - The purpose of this procedure is to provide the direction necessary to comply with Technical Specification boration requirements for failed rod position indicators. This revision changed the old procedure number AOP-ROD-5, Rev. 0 to Sl.OP-AB.ROD-0004(Q), Rev. 0 as part of the Procedure Upgrade Project. The procedure title was changed to encompass additional guidance for failure of Group Step Counter indication. This procedure does not create the possibility of an accident or malfunction of a different type than any previously evaluated in the SAR, nor does it increase the probability or consequences of an accident previously evaluated in the SAR. No changes to the the control rod drives has been made. The method of monitoring once a suspected misaligned control rod is identified is being replaced with the Technical Specification requirement that results in a more detailed method of determining rod position.

(SORC 92-001)

SC.SA-AP.ZZ-0012(Q) "Technical Specification Surveillance Program Matrix" Rev. 14 - This procedure has been revised to reflect the reassignment of departmental responsibility for performance of Technical Specification Surveillance 4.3.4.4.

In addition, the main body of the procedure has been deleted as it is superseded by the instructions in procedure NC.NA-AP.ZZ-0012(Q).

Based on a review of the Technical Specifications, it was determined that this revision will not reduce the margin of safety as defined in the bases for the Technical Specifications. ( SORC 92-003)

Sl.OP-AB.RHR-0002(Q) Loss of RHR at Reduced Inventory" Rev. 0 - The purpose of this procedure is to provide guidance for an RHR System Malfunction with Reactor Vessel water level below the 101' elevation. No sections of the UFSAR contain an analysis of Mid-Loop Operation or loss of RHR while at Mid-Loop conditions. Safety Evaluation S-C-R200-MSE-0738-1 establishes the basis for

• 10CFR50.~9 EVALUATIONS DOCKET NO: 50-272 MONTH: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd}

ITEM

SUMMARY

Mid-Loop Operation. Responses to Generic Letter 87-12, Loss of Decay Heat Removal, Generic Letter 88-17, Loss of Decay Heat Removal, WOG 90-067, Loss of RHR while operating at Mid-Loop Condition, PSE-90-0557, Salem Mid-Loop analysis and WOG ARG-1, and Westinghouse Owners Group Abnormal Response Guidelines provides the bases for the actions in this procedure. (SORC 92-003)

NC.NA-AP.ZZ-0008(Q} "Control of Design and Configuration Change, Tests and Experiments" Rev. 2 - This revision does not constitute a change to the configuration of the facility or the operation of the systems as described in the SAR. Although this procedure establishes a control process for facility changes, each of these changes are supported by individual 10CFR50.59 evaluations. Section 6.0, Administrative Controls, and the Environmental Protection Plan (non-radiological) of both Salem and Hope Creek Technical Specifications are the only pertinent sections. Section 6.0 does not contain any bases; therefore the revision to this procedure does not change the margin of safety in the basis for any Technical Specification.

(SORC 92-007)

MlO-FRS-I-001 "Control Room Fire Response" Rev. 1 - The purpose of this procedure is to provide guidance for the Control Room personnel to take action whenever a verbal report or an alarm is received for a fire.

This procedure replaces procedure AOP-FIRE-1, Rev.

1 for both Units. The procedure still exists, it is only being relocated to improve operational consistency between Site Protection Fire Department and Operations Department to standardize emergency responses within all stations on Artificial Island. The revision to this procedure does not increase the probability or consequences of an accident previously evaluated in the SAR. The revision to the procedure does not increase the probability of occurrence or consequences of malfunction of equipment important to safety previously evaluated in the SAR. There is no reduction of the margin of safety as defined in the basis for any Technical Specification. (SORC 92-007)

"10CFR50.59 EVALUATIONS DOCKET NO: 50-272 MONTH: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd)

ITEM

SUMMARY

MlO-FRS-I-003 "Control Room Emergency Medical Response" Rev. 1 -

The purpose of this procedure is to provide guidance for the Control Room personnel to take action whenever a report of an injured person is received in the Control Room. This procedure replaces procedure SC.OP-AB.MED-OOOl(Q), Rev. O for both Units. The procedure still exists, it is only being relocated to improve operational consistency and to standardize emergency responses within all stations on Artificial Island. The revision to this procedure does not increase the probability or consequences of an accident previously evaluated in the SAR. The revision to the procedure does not. increase the probability of occurrence or consequences of malfunction of equipment important to safety previously evaluated in the SAR. There is no reduction of the margin of safety as defined in the basis for any Technical Specification. (SORC 92-007)

Sl.OP-AB.SW-OOOl{Q) "Loss of Service Water Header Pressure" Rev. 0 -

This procedure is designed to provide the direction necessary for determining and correcting the cause of an abnormal reduction in 11 and/or 12 Service Water header pressure. There is no reduction in the margin of safety as defined in the bases for any Technical Specification. The guidance in this procedure allows the operator to use his systems knowledge to determine how to isolate a leak. Allowing flow to continue to both Component Cooling Water {CCW) Heat Exchangers has no impact on equipment important to safety because a leak in the Diesel Generator service water piping can be isolated with or without service water flow to the CCW Heat Exchangers.

(SORC 92-007)

C. Temporary Modifications {TMOD)

TMR 91-108 "Primary Water Storage Tank (PWST) Cleanup" - The purpose of this TMOD is to clean up the PWST contents, currently contaminated with high chlorides. In order to clean up the contaminated water, a mixed bed demineralizer will be installed in the Dechromating Shed to recycle the PWST

"10CFR50.~9 EVALUATIONS DOCKET NO: 50-272 MONTH: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd)

ITEM

SUMMARY

water. The proposed modification does not impact any equipment other than the PWST which is non-safety related. The malfunctions which are possible under this TMOD include only the PWST and those pieces of equipment associated with this proposal. No safety related equipment would be impacted. The PWST will be isolated from the Primary Water Make Up Pumps during this TMOD and therefore will not affect the quantity or quality of water supplied to these pumps. (SORC 92-003)

TMR 92-001 "Pneumatic Jumper Connecting a Remote Diesel Driven Air Compressor to Control Air at Circulating Water" - The purpose of this TMOD is to provide bottled gas (nitrogen) to control butterfly valves SC9 and SC109 and a diesel compressor to the Circulating Water (CW) vacuum breakers. Installation of this TMOD will support DCP lEC-3140 if it is worked with Unit 1 on line.

The proposed modification affects only the non-safety related portion of the control system which has no impact on the safety related side.

The CW system and the control air it uses performs no safety function. These changes do not alter the original function for which the Control air system is designed. (SORC 92-010)

TMR 92-010 "Temporary Demineralization System Interconnected With the Unit 1 Primary Water Storage Tank (PWST)"

The purpose of this TMOD is to clean up the PWST contents, currently contaminated with high chlorides. In order to clean up the PWST water, it will be recycled through a mixed bed demineralizer installed in the Dechromating Shed.

The PWST is not safety related and is not required for or considered in any safety analysis. The reinforced hoses are rated at 325 psig working pressure, which is above the 200 psi maximum pressure rating for the PWST piping. The maximum pressure to which the hoses will be subjected is 100 psig. All hoses will be routed within a Radiologically Controlled Area (RCA) and will be monitored for development of leaks. The isotopic analysis of water samples taken from the

-10CFR50.59 EVALUATIONS DOCKET NO: 50-272 MONT.H: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 (Cont'd)

ITEM

SUMMARY

PWST indicates that the activity level in the PWST is below 10CR20 limits. Therefore, should a leak occur despite the precautions taken, allowable exposure limits would not be exceeded. The proposal does not reduce the margin of safety as defined in the basis for any Technical Specification. ( SORC 92-011)

D. Safety Evaluations (S/E)

S/E# DES 91-00354 "Increase in Containment Spray Initiation Time"

- This evaluation addresses the increase in the assumed maximum delay time associated with the initiation of Containment Spray. The delay time is now 80 seconds, up 21 seconds from the previous analysis value of 59 seconds. The increase is due entirely to additional water transit time identified by PSE&G. The affect of the increased spray delay time has been analyzed in regard to UFSAR Chapters 15 and 6. In particular, it has been verified that the containment temperature and pressure will not exceed design limits. The results of the safety analyses show that all applicable safety criteria are met and operation of Salem Unit 1 cycle 10 with an increased containment spray delay time does not constitute an unreviewed safety question. (SORC 92-009)

SALEM GENERATING STATION MONTHLY OPERATING

SUMMARY

- UNIT 1 JANUARY 1992 SALEM UNIT NO. 1 The Unit began the period operating at full power, and continued to operate at full power until January 11, 1992, when load was reduced to 50% to test and repair Steam Generator Feed Pump electrical control circuitry. The repairs were completed and a power escalation commenced on January 12, 1992. Turbine valve testing, performed at 85% power, revealed problems with the valve test circuitry. On January 14, 1992, following* completion of repairs, the Unit was returned to 100% power. The Unit continued to operate at essentially full power until January 21, 1992, when it was removed from service due to a control power transformer cable fault and subsequent loss of three circulators. The Unit was returned to 100% power on January 27, 1992, following completion of repairs, and continued to operate at full power throughout the remainder of the period.

_J

REFUELING INFORMATION DOCKET NO: 50-272 MONTH: - JANUARY 1992 UNIT NAME: SALEM 1 DATE: FEBRUARY 10, 1992 COMPLETED BY: J. FEST TELEPHONE: (609)339-2904 MONTH JANUARY 1992

1. Refueling information has changed from last month:

YES NO X

2. Scheduled date for next refueling: APRIL 4, 1992

3. Scheduled date for restart following refueling: JUNE 9, 1992

4. a) Will Technical Specification changes or other license amendments be required?:

YES NO NOT DETERMINED TO DATE -x--

b) Has the reload fuel design been reviewed by the Station Operating Review Committee?:

YES NO - -X --

If no, when is it scheduled?:

5. Scheduled date(s) for submitting proposed licensing action:

N/A

6. Important licensing considerations associated with refueling:

7. Number of Fuel Assemblies:

a. Incore 193

b. In Spent Fuel Storage 588

8. Present licensed spent fuel storage capacity: 1170 Future spent fuel storage capacity: 1170

9. Date of last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity: September. 2001 8-1-7.R4