ML18100B071

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Monthly Operating Rept for Apr 1994 for Salem Generating Station Unit 2.W/940512 Ltr
ML18100B071
Person / Time
Site: Salem PSEG icon.png
Issue date: 04/30/1994
From: Hagan J, Morroni M
Public Service Enterprise Group
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
NUDOCS 9405180383
Download: ML18100B071 (11)
v • d • e


Text

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

Dear Sir:

MONTHLY OPERATING REPORT SALEM NO. 2 DOCKET NO. 50-311 May 12, 1994 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 April 1994 are being sent to you. RH:mp 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, ger -ions cc: Mr. Thomas T. Martin Regional Administrator USNRC Region I 631 Park Avenue King of Prussia, PA 19046 Enclosures 8-1-7.R4 The power is in your hands. / __ 9_4_05 £ so383 -

PDR ADOCK 05000311 R PDR 95-2189 REV 7-92

DAILY UNIT POWER Docket No.: 50-311 Unit Name: Salem #2 Date: 05-10-94 Completed by: Mike Morroni Telephone:

339-2122 Month April 1994 Day Average Daily Power Level Day Average Daily Power Level (MWe-NET) (MWe-NET) 1 665 17 633 2 615 18 618 3 603 19 636 4 709 20 635 5 645 21 640 6 705 22 662 7 518 23 742 8 412 24 764 9 428 25 770 10 431 26 811 11 321 27 794 12 303 28 813 13 472 29 803 14 485 30 245 15 564 31 16 581 P. 8.1-7 Rl

  • OPERATING DATA REPORT e Docket No: Date: Completed by: Mike Morroni Telephone:

Operating Status 1. Unit Name Salem No. 2 Notes 2. Reporting Period April 1994 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} Report, Give Reason NA 9. Power Level to Which Restricted, if any (Net MWe} 10. Reasons for Restrictions, if any 11. Hours in Reporting Period 12. No. of Hrs. Rx. was Critical 13. Reactor Reserve Shutdown Hrs. 14. Hours Generator On-Line 15. Unit Reserve Shutdown Hours 16. Gross Thermal Energy Generated (MWH} Gross Elec. Energy Generated (MWH} 18. Net Elec. Energy Gen. (MWH} 19. Unit Service Factor 20. Unit Availability Factor 21. Unit Capacity Factor (using MDC Net) 22. Unit Capacity Factor (using DER Net) 23. Unit Forced Outage Rate None. This Month 719 719 0 719 0 1540893.6 462090 431914 100 100 54.3 53.9 0 Year to Date 2879 2802 0 2718.3 0 7734552.0 2511130 2387344 94.4 94.4 75.0 74.4 5.6 50-311 05/10/94 339-2122 since Last N/A Cumulative 109992 72081.6 0 69607.8 0 170197491.

4 73057648 69514621 63.3 63.3 57.1 56.7 22.1 24. Shutdowns scheduled over next 6 months (type, date and duration of each) Refueling outage scheduled to start October 15, 1994 and last 60 da s. 25. If shutdown at end of Report Period, Estimated Date of Startup: NA 8-1-7.R2

, NO. DATE 0582 4-7-94 F 0593 4-11-94 F 0592 4-11-94 F 0705 4-30-94 F 1 2 F: Forced S: Scheduled DURATION TYPE 1 (HOURS) REASON 2 14.0 A 8.2 A 17.0 A 16.0 A Reason A-Equipment Failure (explain)

B-Maintenance or Test c-Refuel ing D-Requlatory Restriction UNIT SHUTDOWN AND POWER REDUCTIONS 5 5 5 5 REPORT MONTH APRIL 1994 METHOD OF SHUTTING DOWN REACTOR LICENSE EVENT REPORT # -----------

HF -----------

SH -----------

CH ........................

CB 3 Method: 1-Manual 2-Manual Scram SYSTEM CODE 4 E-Operator Training & License Examination F-Administrative 3-Automatic Scram 4-Continuation of Previous Outage 5-Load Reduction 9-0ther G-Operational Error (Explain)

H-Other (Explain)

COMPONENT CODE 5 PUMP XX VAL VEX PUMPXX INSTRU 4 DOCKET NO. UNIT NAME DATE COMPLETED BY TELEPHONE 50-272 Salem #2

  • 05-10-94 Mike Morroni 339-2122 . CAUSE AND CORRECTIVE ACTI0'1
  • TO PREVENT RECURRENCE INTAKE SYSTEM PROBLEMS INADVERTANT SEC ACTUATION 22 SGFP GOVERNOR REACTOR COOLANT -21 RL FLOW TRANSMITTER 5 Exhibit G -Instructions for Preparation of Data Entry Sheets for Licensee Event Report CLER) File Exhibit 1 -Same Source (NUREG-0161) 10CFR50.59 EVALUATIONS MONTH: -APRIL 1994 DOCKET': UNIT NAME: DATE: COMPLETED BY: TELEPHONE:

50-311 SALEM 2 MAY 10, 1994 R. HELLER {609)339-5162 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 2EC-3268 Pkgs 1&2 "Installation Of Manway And Davit For No. 21 CCHX" -DCP 2EC-3268 entails the installation of an 18" diameter manway and davit on the turnaround side {front) closure head for No. 21 CCHX. In addition, the entire head (wetted side only) will be reclad with a 3/8" thick 90-10 Copper Nickel liner. A new turnaround end closure head will be fabricated and installed on No. 22 CCHX. The new closure head will be designed and fabricated to the same specifications as the modified head on No. 21 CCHX and will include a manway and davit arrangement.

The manways are being added to allow cleaning of the turnaround side tubes and tubesheet of No. 21 & 22 CCHX at power, without having to remove the 72 11 diameter (7900 LB) heat exchanger must be performed during a 72 Hr Tech Spec action statement (3/4.7.4 "Service Water System").

The new manways are similar to the manways installed on the existing s.w. inlet/outlet (rear) closure heads of No. 21 & 22 CCHX's which are used for cleaning the S.W. inlet side tubes and tube sheet. The margin of safety of the component cooling heat exchangers is defined, in part, by the requirements imposed by the ASME code. The design requirements for the proposed modification have been satisfied.

The function of No. 21 & 22 CCHX's has not changed. Ih addition, the proposed modification is being performed during No. 21 & 22 SW nuclear header maintenance outage as allowed by Technical Specification 3.9.8.2 provided the requirements of the subject Technical

  • Specification are satisfied.

The margin of safety is, therefore, unaffected. (SORC 94-027) 2EC-3278 Pkg 1 "Pressurizer Upgrades" -A.) Replacement of Pressurizer Spray Bypass Valves: 2PS2 and 2PS4 will be replaced in their current location.

The associated manual remote valve operators and their flexible shafts will be permanently removed.

10CFR50.59 EVALUATIONS MONTH: -APRIL 1994 (cont'd) ITEM 2EC-3179 Pkg 5

  • DOCKET': UNIT NAME: DATE: COMPLETED BY: TELEPHONE:

SUMMARY

50-311 SALEM 2 MAY 10, 1994 R. HELLER (609)339-5162 B.) Replacement of Cables: Power cables 2A3YACA-A and 2B3YAJA-B and control cables 2A3YAC2B-AT and 2B3YAJ2B-BT, in the pressurizer cubicle, for the MOVs of Pressurizer PORV Stop (Block) Valves 2PR6 and 2PR7 will be replaced with high temperature IEEE 323 and 383 qualified.Rockbestos "Firewall SR" cable. Cables 2A3YACA-A and 2B3YAJA-B will be increased in size from 3/C #12 to 3/C #8 to improve voltage regulation.

C.) Replacement and Relocation of E/P Transducers for Pressurizer Spray Valves: Transducers 2PS1-CONV and 2PS3-CONV for pressurizer spray valves 2PS1 and 2PS3, respectively, will be replaced, retagged 2IP5739 and 2IP5741 and will be relocated to a new panel outside the pressurizer cubicle. Existing cables to the transducers will be pulled back and rerouted to the new panel. Control air supply tubing will be rerouted-from the vicinity.

of the valves to the new panel located outside the pressurizer cubicle. Pneumatic air signal tubing will be routed from the E/Ps in the new panel to the positioners on the valves. Existing valves on the control air supply headers to the 2PS1 and 2PS3 valves will be tagged 2CA1964 and 2CA1965 respectively.

The pressurizer spray valves, the pressurizer spray valve transducers and the pressurizer spray valve bypass valves are not discussed in any of the Technical Specifications or their design bases. Technical Specification 3/4.4.5 requires two PORVs and their block valves to be operable in Modes 1, 2 and 3. The replacement of the EQ power and control cables to the PORV block valves 2PR6 and 2PR7 will be implemented during Mode 5 with the RCS drained and vented. Therefore, this modification will not reduce the margin of safety as defined in the basis for any Technical Specification. (SORC 94-027) "Salem Fire Damper Upgrade" -The design scope for this package includes the replacement

& relocation of existing fire dampers in the Unit 2 switchgear

& Penetration Area Ventilation (SPAV) System. The function, basic configuration and operation of the system will not be altered and the codes, standards, qualification and design criteria of the original 10CFR50.59 EVALUATIONS MONTH: -APRIL 1994 (cont'd) ITEM 2EC-3179 Pkg 7 DOCKET': UNIT NAME: DATE: COMPLETED BY: TELEPHONE:

SUMMARY

50-311 SALEM 2 MAY 10, 1994 R. HELLER (609)339-5162 system will apply. Fire dampers 2CVF-60l, 2CVF-602, 2CVF-603, & 2CVF-810 will be replaced with new fire dampers rated for 3. o hours and relocated to the. fire barrier. New duct sections will be installed in these dampers' present locations.

Fire damper 2CVF-815 is a new 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> damper that will be located in an existing sleeve in the fire barrier. Penetration seal activities required to support this modification involves breaching and resealing a penetration to route temporary power and lighting and the breaching and repair of the penetration seal to facilitate cable removal. The basis for the Technical Specifications does not address either the fire protection features or the SPAV system. The replaced or new fire dampers associated the SPAV system perform no safety related functions.

Since the area temperatures are suitable for the safety related equipment located in the area served by the SPAV system, the equipment is available during this modification.

There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 94-036) "Salem Fire Damper Upgrade" -The design scope for this package Unit 2 includes the addition of a new fire damper and modification of an existing fire damper in the Control Area Air Conditioning System (CAACS). The function, basic configuration and

  • operation of the system will not be altered and the codes, standards, qualification and design criteria of the original system will apply. Fire damper 2CAF-202 will be modified to obtain a 1.5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> rating. Damper 2CAF-203 presently functions as a fire damper & also as a gas control damper interconnected to the Halon 1301 Fire Extinguishing System for the Relay Room. Its fire damper function will be replaced with a ne 1.5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> rated fire damper 2CAF-208 and will be located within the fire barrier. Damper 2CAF-203 will remain as the gas control damper required for the Halon 1301 Fire Extinguishing System; if necessary, this damper will be removed temporarily for access during installation and later returned to its existing 10CFR50.59 EVALUATIONS MONTH: -APRIL 1994 (cont'd) ITEM
  • DOCKET': UNIT NAME: DATE: COMPLETED BY: TELEPHONE:

SUMMARY

50-311 SALEM 2 MAY 10, 1994 R. HELLER (609)339-5162 location.

Fire damper 2CAF-202 and the ductwork between it and the fire barrier will be wrapped with a fire wrap for a 1.5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> fire rating. Fire damper 2CAF-208, which is located in the fire barrier, will not require fire wrap. Existing fire wrap on damper 2CAF-203 is no longer required and will be removed. The basis for the Technical Specifications does not address the fire protection features.

The Technical Specifications discuss the surveillance requirements for the Control Room Emergency Air Conditioning System (EACS) . Since replaced or modified fire dampers associated with the CAAC system perform no safety related functions; these modifications do not affect the safety related system which is required for safe shutdown.

There is no reduction in the margin of safety as.defined in the basis for any Technical Specification. (SORC 94-036) B. Procedures and Revisions S2.0P-SO.CC-0002(Q) 11 21 & 22 Component Cooling Heat Exchanger Operations" -These changes will limit total service water flow if the Service Water (SW) system is challenged by an accident scenario that coincides with a single active component failure of the CCHX flow or temperature control devices. These are temporary restrictions which will be in place only up to a river temperature of 10° Fahrenheit.

DCPs lEC-3316 and 2EC-3274 will be installed prior to the river temperature reaching 10°. These two DCPs will address the excess flow through the CCHXs resulting from a flow control device failure, by means of a fixed restriction (manual valve permanently throttled) . Engineering Calculation S-C-SW-MDC-1347 demonstrates that with these operating procedure revisions, the CCHX will satisfy normal plant operating conditions for the rejection of heat and will also perform the required design function for heat rejection from the Component Cooling System during the most limiting accident scenario.

  • This proposal will result in no reduction in SWS flow to the CCHXs. This flow reduction does not reduce the capability of the CCHXs to perform 10CFR50.59 EVALUATIONS MONTH: -APRIL 1994 (cont'd) ITEM
  • DOCKET I: UNIT NAME: DATE: COMPLETED BY: TELEPHONE:

SUMMARY

50-311 SALEM 2 MAY 10, 1994 R. HELLER (609)339-5162 their intended design function.

There is no reduction in the margin of safety as defined in the bases for any Technical Specification. (SORC 94-032)

SALEM UNIT NO. 2

  • SALEM GENERATING STATION MONTHLY OPERATING

SUMMARY

-UNIT 2 APRIL 1994 Reactor power varied during the period as a precautionary measure due to the continuous challenges of heavy grass at the circulator inlet area. Reactor power was gradually increased from approximately 40% to approximately 80% over the period from April 11-29, 1994, as river grass conditions improved.

On April 29, 1994, power was reduced to approximately 25% for repairs to a reactor coolant system flow transmitter.

The Unit continued operating at reduced power throughout the remainder of the period as repairs were performed.

. .

INFORMATION MONTH: -APRIL 1994 . ,I S-MONTH APRIL 1994 DOCKET': UNIT NAME: DATE: COMPLETED BY: TELEPHONE:

1. Refueling information has changed from last month: YES NO
2. Scheduled date for next refueling:

OCTOBER 15, 1994 50-311 SALEM 2 MAY 10, 1994 R. HELLER (609)339-5162

3. Scheduled date for restart following refueling:

DECEMBER 13, 1994 4. a) Will Technical Specification changes or other license amendments be required?:

YES NO NOT DETERMINED TO DATE b) Has the reload fuel design been reviewed by the Station Operat:j_ng Review Committee?:

YES NO If no, when is it scheduled?:

OCTOBER 94 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 492 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:

March 2003 8-1-7.R4

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