ML18100B071: Difference between revisions
StriderTol (talk | contribs) (Created page by program invented by StriderTol) |
StriderTol (talk | contribs) (Created page by program invented by StriderTol) |
||
(One intermediate revision by the same user not shown) | |||
Line 17: | Line 17: | ||
=Text= | =Text= | ||
{{#Wiki_filter:,. | {{#Wiki_filter:,. | ||
* 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 | PS~G | ||
* Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station May 12, 1994 U.S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 | |||
==Dear Sir:== | ==Dear Sir:== | ||
DAILY UNIT POWER Docket No.: 50-311 Unit Name: Salem #2 Date: 05-10-94 Completed by: Mike Morroni Telephone: | MONTHLY OPERATING REPORT SALEM NO. 2 DOCKET NO. 50-311 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. | ||
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 | 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 - | ||
* OPERATING DATA REPORT e Docket No: Date: Completed by: Mike Morroni Telephone: | ions RH:mp 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 - 940_4_3_0--~, | ||
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) | PDR ADOCK 05000311 R PDR 95-2189 REV 7-92 | ||
~ERAGE DAILY UNIT POWER L~ | |||
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: 50-311 Date: 05/10/94 Completed by: Mike Morroni Telephone: 339-2122 Operating Status | |||
: 1. Unit Name Salem No. 2 Notes | |||
CH ........................ | : 2. Reporting Period April 1994 | ||
CB 3 Method: 1-Manual 2-Manual Scram | : 3. Licensed Thermal Power (MWt} 3411 | ||
H-Other (Explain) | : 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 | |||
The Station Operations Review Committee has reviewed and concurs with these evaluations. | : 9. Power Level to Which Restricted, if any (Net MWe} N/A | ||
ITEM | : 10. Reasons for Restrictions, if any None. | ||
This Month Year to Date Cumulative | |||
: 11. Hours in Reporting Period 719 2879 109992 | |||
: 12. No. of Hrs. Rx. was Critical 719 2802 72081.6 | |||
: 13. Reactor Reserve Shutdown Hrs. 0 0 0 | |||
: 14. Hours Generator On-Line 719 2718.3 69607.8 | |||
: 15. Unit Reserve Shutdown Hours 0 0 0 | |||
: 16. Gross Thermal Energy Generated (MWH} 1540893.6 7734552.0 170197491. 4 Gross Elec. Energy Generated (MWH} 462090 2511130 73057648 | |||
: 18. Net Elec. Energy Gen. (MWH} 431914 2387344 69514621 | |||
: 19. Unit Service Factor 100 94.4 63.3 | |||
: 20. Unit Availability Factor 100 94.4 63.3 | |||
: 21. Unit Capacity Factor (using MDC Net) 54.3 75.0 57.1 | |||
: 22. Unit Capacity Factor (using DER Net) 53.9 74.4 56.7 | |||
: 23. Unit Forced Outage Rate 0 5.6 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 | |||
UNIT SHUTDOWN AND POWER REDUCTIONS REPORT MONTH APRIL 1994 DOCKET NO. 50-272 UNIT NAME Salem #2 | |||
* DATE 05-10-94 COMPLETED BY Mike Morroni TELEPHONE 339-2122 METHOD OF SHUTTING LICENSE DURATION DOWN EVENT SYSTEM COMPONENT CAUSE AND CORRECTIVE ACTI0'1 | |||
* NO. DATE TYPE 1 (HOURS) REASON 2 REACTOR REPORT # CODE 4 CODE 5 TO PREVENT RECURRENCE 0582 4-7-94 F 14.0 A 5 ----------- HF PUMP XX INTAKE SYSTEM PROBLEMS 0593 4-11-94 F 8.2 A 5 ----------- SH VAL VEX INADVERTANT SEC ACTUATION 0592 4-11-94 F 17.0 A 5 ----------- CH PUMPXX 22 SGFP GOVERNOR 0705 4-30-94 F 16.0 A 5 ........................ CB INSTRU REACTOR COOLANT - 21 RL FLOW TRANSMITTER 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-Refuel ing 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) | |||
10CFR50.59 EVALUATIONS DOCKET': 50-311 MONTH: - APRIL 1994 UNIT NAME: SALEM 2 DATE: MAY 10, 1994 COMPLETED BY: R. HELLER TELEPHONE: {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== | ==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"). | A. Design Change Packages 2EC-3268 Pkgs 1&2 "Installation Of Manway And Davit For No. 21 CCHX" - | ||
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. | DCP 2EC-3268 entails the installation of an 18" diameter manway and davit on the turnaround side | ||
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 | {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 & | ||
* Specification are satisfied. | 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 | ||
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. | * 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. | ||
The associated manual remote valve operators and their flexible shafts will be permanently removed. | |||
10CFR50.59 EVALUATIONS MONTH: -APRIL 1994 | 10CFR50.59 EVALUATIONS MONTH: - APRIL 1994 | ||
* DOCKET': UNIT NAME: DATE: COMPLETED BY: TELEPHONE: | * DOCKET': | ||
UNIT NAME: | |||
DATE: | |||
COMPLETED BY: | |||
50-311 SALEM 2 MAY 10, 1994 R. HELLER TELEPHONE: (609)339-5162 (cont'd) | |||
ITEM | |||
==SUMMARY== | ==SUMMARY== | ||
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. | 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: | ||
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. | 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. | ||
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 | 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) 2EC-3179 Pkg 5 "Salem Fire Damper Upgrade" - The design scope for this package includes the replacement & relocation of existing fire dampers in the Unit 2 switchgear & | ||
& 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 DOCKET': 50-311 MONTH: - APRIL 1994 UNIT NAME: SALEM 2 DATE: MAY 10, 1994 COMPLETED BY: R. HELLER TELEPHONE: (609)339-5162 (cont'd) | |||
ITEM | |||
==SUMMARY== | ==SUMMARY== | ||
Fire damper 2CVF-815 is a new 3 hour 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. | 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. | ||
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. | fire barrier. New duct sections will be installed in these dampers' present locations. Fire damper 2CVF-815 is a new 3 hour damper that will be located in an existing sleeve in the fire barrier. | ||
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 | 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) 2EC-3179 Pkg 7 "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 hour 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 hour 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 | * 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 hour 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 hour 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 | ||
* DOCKET': UNIT NAME: DATE: COMPLETED BY: TELEPHONE: | |||
10CFR50.59 EVALUATIONS MONTH: - APRIL 1994 | |||
* DOCKET': | |||
UNIT NAME: | |||
DATE: | |||
COMPLETED BY: | |||
50-311 SALEM 2 MAY 10, 1994 R. HELLER TELEPHONE: (609)339-5162 (cont'd) | |||
ITEM | |||
==SUMMARY== | ==SUMMARY== | ||
Fire damper 2CAF-202 and the ductwork between it and the fire barrier will be wrapped with a fire wrap for a 1.5 hour 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. | 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 hour 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 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. | 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) | ||
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. | B. Procedures and Revisions S2.0P-SO.CC-0002(Q) 11 21 & 22 Component Cooling Heat Exchanger Operations" - These changes will limit th~ 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. | ||
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 | ||
* 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 | |||
* DOCKET I: UNIT NAME: DATE: COMPLETED BY: TELEPHONE: | 10CFR50.59 EVALUATIONS MONTH: - APRIL 1994 | ||
* DOCKET I: | |||
UNIT NAME: | |||
DATE: | |||
COMPLETED BY: | |||
50-311 SALEM 2 MAY 10, 1994 R. HELLER TELEPHONE: (609)339-5162 (cont'd) | |||
ITEM | |||
==SUMMARY== | ==SUMMARY== | ||
There is no reduction in the margin of safety as defined in the bases for any Technical Specification. (SORC 94-032) | 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 GENERATING STATION MONTHLY OPERATING | * SALEM GENERATING STATION MONTHLY OPERATING | ||
==SUMMARY== | ==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. | - UNIT 2 APRIL 1994 SALEM UNIT NO. 2 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. | ||
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. | R~FUELING INFORMATION DOCKET': 50-311 MONTH: - APRIL 1994 UNIT NAME: SALEM 2 | ||
,I | |||
INFORMATION MONTH: -APRIL 1994 | .S-DATE: MAY 10, 1994 COMPLETED BY: R. HELLER TELEPHONE: (609)339-5162 MONTH APRIL 1994 | ||
: 1. Refueling information has changed from last month: YES NO | : 1. Refueling information has changed from last month: | ||
: 2. Scheduled date for next refueling: | YES NO ~-*=X~~ | ||
OCTOBER 15, 1994 | : 2. Scheduled date for next refueling: OCTOBER 15, 1994 | ||
: 3. Scheduled date for restart following refueling: | : 3. Scheduled date for restart following refueling: DECEMBER 13, 1994 | ||
DECEMBER 13, 1994 4. a) Will Technical Specification changes or other license amendments be required?: | : 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 NOT DETERMINED TO DATE ~=X~- | ||
YES NO If no, when is it scheduled?: | b) Has the reload fuel design been reviewed by the Station Operat:j_ng Review Committee?: | ||
OCTOBER 94 5. Scheduled date(s) for submitting proposed licensing action: N/A 6. Important licensing considerations associated with refueling: | YES NO ~-=X~~ | ||
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: | : 7. Number of Fuel Assemblies: | ||
: a. Incore 193 b. In Spent Fuel Storage 492 8. Present licensed spent fuel storage capacity: | : a. Incore 193 | ||
1170 Future spent fuel storage capacity: | : b. In Spent Fuel Storage 492 | ||
: 8. Present licensed spent fuel storage capacity: 1170 Future spent fuel storage capacity: 1170 | |||
March 2003 8-1-7.R4}} | : 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}} |
Latest revision as of 05:58, 3 February 2020
ML18100B071 | |
Person / Time | |
---|---|
Site: | Salem ![]() |
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) | |
Text
,.
PS~G
- Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station May 12, 1994 U.S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555
Dear Sir:
MONTHLY OPERATING REPORT SALEM NO. 2 DOCKET NO. 50-311 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.
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 RH:mp 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 - 940_4_3_0--~,
PDR ADOCK 05000311 R PDR 95-2189 REV 7-92
~ERAGE DAILY UNIT POWER L~
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: 50-311 Date: 05/10/94 Completed by: Mike Morroni Telephone: 339-2122 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} since Last Report, Give Reason NA
- 9. Power Level to Which Restricted, if any (Net MWe} N/A
- 10. Reasons for Restrictions, if any None.
This Month Year to Date Cumulative
- 11. Hours in Reporting Period 719 2879 109992
- 12. No. of Hrs. Rx. was Critical 719 2802 72081.6
- 13. Reactor Reserve Shutdown Hrs. 0 0 0
- 14. Hours Generator On-Line 719 2718.3 69607.8
- 15. Unit Reserve Shutdown Hours 0 0 0
- 16. Gross Thermal Energy Generated (MWH} 1540893.6 7734552.0 170197491. 4 Gross Elec. Energy Generated (MWH} 462090 2511130 73057648
- 18. Net Elec. Energy Gen. (MWH} 431914 2387344 69514621
- 19. Unit Service Factor 100 94.4 63.3
- 20. Unit Availability Factor 100 94.4 63.3
- 21. Unit Capacity Factor (using MDC Net) 54.3 75.0 57.1
- 22. Unit Capacity Factor (using DER Net) 53.9 74.4 56.7
- 23. Unit Forced Outage Rate 0 5.6 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
UNIT SHUTDOWN AND POWER REDUCTIONS REPORT MONTH APRIL 1994 DOCKET NO. 50-272 UNIT NAME Salem #2
- DATE 05-10-94 COMPLETED BY Mike Morroni TELEPHONE 339-2122 METHOD OF SHUTTING LICENSE DURATION DOWN EVENT SYSTEM COMPONENT CAUSE AND CORRECTIVE ACTI0'1
- NO. DATE TYPE 1 (HOURS) REASON 2 REACTOR REPORT # CODE 4 CODE 5 TO PREVENT RECURRENCE 0582 4-7-94 F 14.0 A 5 ----------- HF PUMP XX INTAKE SYSTEM PROBLEMS 0593 4-11-94 F 8.2 A 5 ----------- SH VAL VEX INADVERTANT SEC ACTUATION 0592 4-11-94 F 17.0 A 5 ----------- CH PUMPXX 22 SGFP GOVERNOR 0705 4-30-94 F 16.0 A 5 ........................ CB INSTRU REACTOR COOLANT - 21 RL FLOW TRANSMITTER 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-Refuel ing 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)
10CFR50.59 EVALUATIONS DOCKET': 50-311 MONTH: - APRIL 1994 UNIT NAME: SALEM 2 DATE: MAY 10, 1994 COMPLETED BY: R. HELLER TELEPHONE: {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
- DOCKET':
UNIT NAME:
DATE:
COMPLETED BY:
50-311 SALEM 2 MAY 10, 1994 R. HELLER TELEPHONE: (609)339-5162 (cont'd)
ITEM
SUMMARY
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) 2EC-3179 Pkg 5 "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 DOCKET': 50-311 MONTH: - APRIL 1994 UNIT NAME: SALEM 2 DATE: MAY 10, 1994 COMPLETED BY: R. HELLER TELEPHONE: (609)339-5162 (cont'd)
ITEM
SUMMARY
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) 2EC-3179 Pkg 7 "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
- DOCKET':
UNIT NAME:
DATE:
COMPLETED BY:
50-311 SALEM 2 MAY 10, 1994 R. HELLER TELEPHONE: (609)339-5162 (cont'd)
ITEM
SUMMARY
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 th~ 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
- DOCKET I:
UNIT NAME:
DATE:
COMPLETED BY:
50-311 SALEM 2 MAY 10, 1994 R. HELLER TELEPHONE: (609)339-5162 (cont'd)
ITEM
SUMMARY
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 GENERATING STATION MONTHLY OPERATING
SUMMARY
- UNIT 2 APRIL 1994 SALEM UNIT NO. 2 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.
R~FUELING INFORMATION DOCKET': 50-311 MONTH: - APRIL 1994 UNIT NAME: SALEM 2
,I
.S-DATE: MAY 10, 1994 COMPLETED BY: R. HELLER TELEPHONE: (609)339-5162 MONTH APRIL 1994
- 1. Refueling information has changed from last month:
YES NO ~-*=X~~
- 2. Scheduled date for next refueling: OCTOBER 15, 1994
- 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 ~=X~-
b) Has the reload fuel design been reviewed by the Station Operat:j_ng Review Committee?:
YES NO ~-=X~~
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