ML13324A703

Forwards Revised Integrated Living Schedule & Revised Proposed License Condition & Plan to Support Issuance of License Condition 3.J, Integrated Living Schedule of Backfits

ML13324A703
Person / Time
Site:	San Onofre
Issue date:	08/29/1985
From:	Medford M SOUTHERN CALIFORNIA EDISON CO.
To:	Zwolinski J Office of Nuclear Reactor Regulation
References
TAC-54376, NUDOCS 8509030207
Download: ML13324A703 (17)

Text

Southern California Edison Company P. 0. BOX 800 2244 WALNUT GROVE AVENUE ROSEMEAD. CALIFORNIA 91770 M.O.MEDFORD TELEPHONE MANAGER, NUCLEAR LICENSING August 29, 1985 (818) 302-1749 Director, Office of Nuclear Reactor Regulation Attention:

Mr. 3. A. Zwolinski, Chief Operating Reactors Branch No. 5 Division of Licensing U. S. Nuclear Regulatory Commission Washington, D.C.

20555 Gentlemen:

Subject:

Docket No. 50-206 Integrated Living Schedule Revision San Onofre Nuclear Generating Station Unit 1

References:

A. Letter, Kenneth P. Baskin, SCE, to H. R. Denton, NRC, dated February 27, 1984 B. Letter, Kenneth P. Baskin, SCE, to H. R. Denton, NRC, dated December 6, 1983 C. Letter, Kenneth P. Baskin, SCE, to H. R. Denton, NRC, dated May 23, 1984 The Reference A letter provided the regulatory projects (Schedule B) of SCE's Integrated Living Schedule (ILS) of backfits which spanned the next three cycles of plant operation. Reference B submitted an earlier version of the regulatory projects schedule and also included the betterment projects schedule (Schedule C).

Reference C submitted a license amendment application to codify the ILS Program Plan (the "Plan") as a license condition. The Plan is designed such that SCE will provide periodic updates of schedules for backfits on San Onofre Unit 1. This letter provides a revised ILS and revisions to the proposed license condition and Plan in order to support issuance of license condition 3.3 "Integrated Living Schedule of Backfits." is a revision of the proposed license condition which simplifies the condition and removes the built-in expiration date. is a revision of the Plan which the license condition requires SCE to follow. The major revisions to the Plan include the following:

(1) The San Onofre Change Committee is identified as the source of priority and schedule determinations for betterment projects (Schedule C).

8509030207 850829 PDR ADOCK 05000206 P

PDR

Mr. J.

August 29, 1985 (2) Resource allocation between regulatory and betterment projects will no longer be specified.

(3) Since the Plan itself is not a part of the license,Section VIII "Modifications to the Plan" has been changed to indicate that revisions may be submitted for NRC approval without going through the license amendment process.

Number (2) above has been deemed appropriate due to the resource allocation for the upcoming outage which is almost entirely dedicated to regulatory projects. It should also be noted that the three month outage length constraint is expected to be doubled during the outage. Notwithstanding these facts, SCE is still strongly committed to the ILS philosophy. includes revised schedules A, B and C as updated according to the provisions of the Plan and also includes a periodic update as specified in section V.A of the Plan.

The next periodic update will be provided six months following NRC issuance of the implementing license condition.

If there are any questions on this information please let me know.

Very truly yours, Enclosures cc:

Mr. 3. B. Martin, NRC Region V REVISION OF LICENSE CONDITION

3.3 PROPOSED CHANGE

NO. 134 SAN ONOFRE NUCLEAR GENERATING STATION, UNIT 1 The License Condition 3.3, "Integrated Living Schedule of Backfits," that was proposed by License Amendment Application No. 119 should be changed as follows.

The revised license condition simplifies the wording and deletes the built-in expiration date.

Revised Proposed Condition 3.3 Integrated Living Schedule of Backfits

1. Southern California Edison Company shall implement a plan for scheduling all capital backfits based on the Integrated Living Schedule Program Plan (the "Plan").

a. The Plan shall be followed by the licensee from and after the effective date of this amendment.

b. Changes to completion dates for items identified in Schedules B and C do not require a license amendment. Dates specified in Schedule A shall be changed only in accordance with applicable NRC procedures.

GEH:4583F INTEGRATED LIVING SCHEDULE PROGRAM PLAN SAN ONOFRE NUCLEAR GENERATING STATION, UNIT 1 I. INTRODUCTION This document provides the methodology to be used in determining the implementation schedules of capital projects at San Onofre Unit 1 in accordance with the provisions of License Condition 3.J.

The program has as its goal the implementation of capital backfits in a stable, controlled manner with the implementation of projects with the greatest potential for enhancing the safe operation of the unit generally given highest priority. The projects of regulatory origin will be ranked using the Westinghouse Analytical Ranking Process to specifically determine the relative potential safety contribution of each backfit. The safety ranking will then be used as a primary criterion in scheduling the backfits.

For betterment projects the priority and schedule will be determined by the San Onofre Change Committee. The Change Committee consists of management representatives involved in all areas of plant operation and is the most effective means of determining implementation schedules for those projects necessary for continued or improved plant operation, maintenance, etc.

The program reflects limited outage time and financial and manpower resources, while at the same time implementing those backfits deemed necessary for enhanced plant safety. The plan provides for integration of all future identified work into one comprehensive schedule and has built-in mechanisms for changes to the schedule when new modifications are identified or when key program milestones cannot be achieved due to considerations beyond the control of SCE.

II.

SUMMARY

OF PRIORITY DETERMINATION The Integrated Living Schedule (ILS) is based on a priority determination to assist in maximizing the benefit derived from backfits.

Since it is not always possible or beneficial to try to implement a large number of backfits in a single outage, the ILS provides a mechanism for focusing attention on those projects of highest priority.

Regulatory related projects will be ranked using the Westinghouse Analytical Ranking Process.

This process was approved by the NRC in their letter from D. G. Eisenhut, NRC, to K. P. Baskin, SCE, dated November 16, 1983. A description of the Westinghouse process was submitted to the NRC by letter dated September 2, 1983 from Kenneth P.

Baskin to H. R. Denton.

-2 Betterment projects do not always have a major direct safety impact and vary in their effect on operation, maintenance, ALARA, reliability, availability, etc.

These projects also vary in magnitude from those requiring a small expenditure of resources to those requiring substantial resources and outage time. In many instances the implementation of a betterment project may be necessary on an expedited schedule due to an anticipated negative impact on plant operation. Due to these and other factors, the betterment projects will have their priority and schedule determined by the San Onofre Change Committee. The Change Committee is incorporated into the review cycle for approval of plant modifications by San Onofre Procedure SO123-XIX-3.0. This committee consists of representatives from all areas of plant operation and management. In this way special consideration can be given to particular attributes of a betterment project that may make it imperative to implement on an expedited schedule.

III. SCHEDULING Once the projects have been ranked they will be scheduled using normal scheduling methods.

The projects ranked highest will first be evaluated to determine whether they can be implemented during the next scheduled refueling outage. Projects will continue to be selected from the top of the ranked lists and scheduled for the earliest outage in which implementation constraints of a three month outage have not been exceeded. These schedules will then be separated into three lists as described below:

Schedule A All items which have implementation dates required by NRC rules, Orders or License Conditions.

Schedule B Regulatory items (of either generic or plant specific nature) identified by the NRC which have specific backfits identified and which SCE has agreed to implement, or items perceived by SCE as prospective NRC requirements, or major tasks resulting from mandates of agencies other than the NRC.

Also included are evaluations for major NRC initiated issues that are necessary either to determine the effect of a generic issue or to determine any actions (backfit or otherwise) necessary to resolve an NRC safety concern.

Schedule C Southern California Edison initiated plant betterment projects.

-.3 Schedule A dates may be modified only with prior NRC approval in accordance with existing NRC procedures. Changes in Schedule B dates require written notification to the NRC as described in Section V below.

Schedule C dates are provided as information to allow the NRC to gain perspective on the current backfit load and may be changed at SCE discretion. Schedules A, B and C taken together provide the basis for assessing the overall effect of changes to schedules and serve as a departure point for discussion between the NRC and SCE regarding such changes, as discussed below.

IV. SCHEDULE MODIFICATIONS An important aspect of SCE's planning effort is the recognition that the schedules will need to be modified at times to reflect changes in regulatory requirements, to accommodate those activities that SCE finds necessary to improve plant efficiency and reliability, and to take into account delays resulting from events beyond SCE's control.

It is important that the procedure used by SCE for changing the schedules be documented.-*/ In addition, the NRC must play a role in the oversight of the scheduling process (and must, in fact, judge the acceptability of proposed date changes in Schedule A).

Accordingly, it is important that the NRC's role, and the interaction between the NRC and SCE be clearly defined, as discussed below.

V. SOUTHERN CALIFORNIA EDISON COMPANY RESPONSIBILITIES The Integrated Living Schedule requires that SCE monitor the progress of the work undertaken, manage its activities to maintain the schedule, and act promptly to take necessary actions when a schedule change is needed.

A.

Periodic Updating Southern California Edison will update Schedules A, B and C semi-annually and submit the revised schedules to the NRC beginning six months following NRC approval of the Plan.

In addition to updating the schedules, SCE will:

o Summarize progress in implementing NRC requirements concerning plant modifications.

o Identify changes since the last report.

• /

Schedules A, B and C will contain sufficient detail to identify those backfits with completion dates keyed to fuel cycle outages. The schedules may also contain specific dates (either calendar date or keyed to some other milestone) for major evaluations. In any case, a change in outage period shall not be considered a schedule change.

0

-4 o

Summarize the reasons for schedule changes associated with Schedules A and B.

o Indicate the expected percentage allocation of resources on Regulatory and Betterment projects for the next refueling/

backfit outage.

B. Changes to Schedules Changes to the schedules may arise from a variety of reasons, such as new work activities; modifications to the scope of scheduled work; problems in delivery, procurement, etc.; changes in NRC rules and regulations; or other NRC or SCE actions.

Where it is necessary to add a new work item or to change the schedule for an item, the following general guidance will be utilized to the extent appropriate:

o Determine the priority of the project, or changed priority, using the Westinghouse Analytical Ranking Process.

o Schedule the new or changed item to avoid rescheduling other items already well underway, if it can be reasonably achieved.

o Alter Schedule B and C items before Schedule A items unless priorities indicate that a Schedule A project should be rescheduled by appropriate Commission procedures.

o Select a schedule for the new or changed item which will help maintain an optimum integrated program of work.

As noted above, no changes will be made to Schedule A without prior NRC approval.

Should a change become necessary, it will only be proposed after SCE has determined that rescheduling of lower priority work either will not significantly assist in scheduling Schedule A without change, or that the safety, cost or schedule penalties from rescheduling lower priority work significantly outweigh the change in a Schedule A completion date.

SCE will inform the NRC Project Manager when serious consideration is given to requesting a change in Schedule A. When SCE determines that a change in Schedule A is necessary, it will submit a written request for NRC approval in accordance with applicable procedures.

Work items in Schedule B may be rescheduled or work items may be added to Schedule B by SCE without NRC approval; however, SCE will inform the NRC Project Manager as early as possible when serious consideration is given to significantly changing the schedule or adding an item in Schedule B.

-5 When SCE adopts a significant change for an item in Schedule B, it will provide the NRC written notification thereof, including the reasons therefore and information on any necessary compensatory actions. The NRC may request further explanation or discussion concerning such change. In this event, discussions will be initiated with the NRC Project Manager. However, SCE changes to scheduled dates will be effective unless subsequently modified by SCE.

Work items in Schedule C may be rescheduled or work items may be added to Schedule C by SCE without NRC notification. SCE will report changes to Schedule C items in its semi-annual update to be provided in accordance with Section V.A above. This schedule is provided for information purposes only and is intended to give the NRC a better understanding of the unit's overall backfit program.

VI.

NRC REVIEW As pointed out in Section V.B above, changes to the schedules are inevitable. Actions required by the NRC are discussed below:

A.

Southern California Edison Originated Changes

1. Upon receipt from SCE of a request for modification of Schedule A, NRC will act promptly (consistent with resource availability and priority of other work) to act on the request in accordance with applicable procedures.

2. If the request for a modification of Schedule A is denied, the NRC shall promptly inform SCE and provide the reasons for denial.

3. NRC consideration of SCE changes in non-Schedule A items is covered by V.B above.

B.

NRC Originated Changes (Schedule A)

It is recognized that formal NRC regulatory actions may:

(1) impose a new regulatory requirement with a fixed date or (2) establish a firm date for a previously identified regulatory requirement. In taking any such action, the NRC, to the extent consistent with its overall regulatory responsibilities and, unless public health, safety, or interest require otherwise, will take into account the impact of such action on SCE's ability to complete effectively the items on Schedules A, B and C, and, in consultation with SCE, will try to minimize such impact. Although any formal regulatory action taken by the NRC will be effective in accordance with its terms without inclusion in Schedule A, the NRC and SCE recognize the desirability of incorporating such action into Schedule A, particularly in order to incorporate at the same time any other

appropriate changes in the total integrated schedule program.

Accordingly, once such formal regulatory action is taken (or earlier, if practicable), the NRC will provide SCE a reasonable opportunity to propose overall changes in the total integrated schedule program which would most effectively accommodate such requirements.

Any resulting changes in items in Schedule A will be approved by the NRC in accordance with established procedures, and will thereupon be reflected in a revised Schedule A submitted by SCE. SCE will inform the NRC of any resulting changes in Schedule B in accordance with Section V. above.

C. New NRC Issues (Schedule B)

The NRC may, from time to time, identify new regulatory issues which may result in plant modifications.

For issues on which the NRC requests scheduling information, these issues may be included in Schedule B in accordance with Sections II and III above. As for the case of NRC originated changes to Schedule A items, the NRC will provide SCE a reasonable opportunity to propose overall changes in the total ILS which would most effectively accommodate such issues.

Any resulting changes in schedules will thereupon be reflected in revised Schedules submitted by SCE.

VIII.MODIFICATIONS TO THE PLAN The licensee and the NRC recognize that the Plan itself may require future revision. Accordingly, if such a change is deemed necessary by SCE, a revised Plan may be submitted for NRC approval. The revised plan will become effective upon notification to SCE of NRC approval.

GEH:3989F INTEGRATED LIVING SCHEDULE UPDATE SAN ONOFRE UNIT 1 SCE's first edition of the Integrated Living Schedule (ILS) was submitted in letters dated December 6, 1983 and February 27, 1984. The schedules enclosed with those letters have been revised using the ILS Program Plan and are included below. This enclosure also provides an update in accordance with the provisions of the ILS Plan.

Schedule Changes The previously submitted regulatory schedule (Schedule B) has been revised to take into account the completion of three projects, reevaluation and resolution without backfit of two projects and the addition of five previously unscheduled regulatory projects.

The three projects that are now complete are as follows:

1.

Efcomatic Actuator Replacement: This project was completed as part of the 1984 Return-to-Service Program and was previously scheduled for Cycle 9.

2.

Electrical Drawing Verification Project:

This project is now complete and was previously scheduled for Cycle 9.

3.

Replacement of SV99 Actuation Circuit:

This project was completed as part of the Return--to-Service Program and was previously scheduled for Cycle 9.

Two projects have been reevaluated and resolved without the need for backfIts as indicated below:

1. The NIS Rockbestos Cable Replacement Project:

As part of the ongoing Environmental Qualification Program, it has been determined that these cables are not required in a post-accident condition.

2. Solidified Resin Storage Facility Project:

Plans to install a facility for the storage of solidified resins at SONGS 1 have been cancelled as the facilities of SONGS 2 and 3 will be utilized as necessary.

The five additional projects are as follows:

1.

Boric Acid System Gas Binding:

This project concerns the accumulation of gases in the boric acid transfer system and has been the cause of repeated concern with NRC Region V and the Operations Staff.

This modification received a high ranking using the Westinghouse Analytical Ranking Process and is scheduled for work as possible during the upcoming outage but is indicated as a Cycle 10 completion project.

2. Containment Airlock Operating Mechanism:

This project was previously scheduled as a betterment project but has now been

included in the regulatory (Schedule B) list. The operating mechanism continues to be a source of repeated maintenance and is a concern of NRC Region V.

3.

Degraded Grid Voltage Modifications:

By letter from M. 0. Medford, SCE, to W. A. Paulson, NRC, dated September 20, 1984, it was indicated that a degraded grid voltage protection system would be installed. This project has been scheduled for Cycle 10 implementation.

4. Main Feedwater Low Flow Indication:

This project is being added to the regulatory list as a Cycle 9 project.

Low Flow indication was previously installed on the Feedwater System but due to reliability problems will be replaced.

5. Magnecraft Relay Replacement: The Magnecraft relays used in the voltage regulators of the Diesel Generators will be replaced due to IE Bulletin 84-02, "Failure of G.E. type HFA Relays in use in Class 1E Safety Systems."

SCE committed to replace these relays in a letter from M. 0. Medford, SCE, to J. B. Martin, NRC, dated July 30, 1984. This project has been scheduled for Cycle 10.

In addition to these completed and added projects, the Health Physics facility upgrade previously scheduled for Cycle 11 implementation has now been rescheduled to be completed during the upcoming outage.

This change in schedule is not due to a change in ranking by the Westinghouse Analytic Ranking Process, rather it is required to meet requirements set forth by SCE's insurer.

Resource Allocation During the upcoming refueling outage, resources are expected to be more than 90% regulatory related. In addition, the outage is scheduled to last approximately twice the normal three months and require SCE to expend half again the resources expected during a typical refueling outage.

Revised Schedules The revised schedules associated with the SONGS 1 ILS are as follows:

SCHEDULE A Projects with implementation dates required by NRC rules, orders or license conditions.

Cycle for Prolect Implementation*

1. Modifications associated with 9

10 CFR 50, Appendix R Cycle for implementation indicates the refueling/backfit outage which precedes a cycle of operation -

e.g., Cycle 8 will be completed in November 1985 at which time the Cycle 9 refueling/backfit outage will take place.

-3 Cycle for Project Implementation

2.

Long Term Seismic Program 9

Contingent Rescission of Suspension, November 21, 1984

3. Environmental Qualification 9

10 CFR 50.49

4.

Post Accident Sampling System 9

License Condition 3.K SCHEDULE B Regulatory items identified by the NRC which have specific backfits identified and which SCE has agreed to implement, or items perceived by SCE as prospective NRC requirements, or major tasks resulting from mandates of agencies other than the NRC.

Also included are evaluations for major NRC initiated issues that are necessary either to determine the effect of a generic issue or to determine any actions (backfit or otherwise) necessary to resolve an NRC safety concern.

Cycle for Project Implementation

1. Containment Airlock Operating 9

Mechanism

2. Regulated Instrument Buses 9

3. Safety Grade Upgrade of AFWS 9

Equipment

4. Health Physics Facility Upgrade 9

5. CVCS Valves MOV-LCV-1100B,C,D 9

6. Waste Gas Decay Tank Monitoring 9

Instrumentation

7.

Improvements to Operational 9

Radiation Monitoring System

8. Main Feedwater Low Flow Instrumentation 9

9.

Radiological Effluent Technical 9

Specification Modifications

10.

Magnecraft Relay Replacement 10

11.

Boric Acid System Gas Binding 10

12.

Third Train of Auxiliary Feedwater 10

-4 Cycle for Project Implementation

13.

Safety Injection System Modifications 10

14.

Replacement of Cable to RHR Pumps 10

15.

Reactor Coolant Pump Lift Rigs 11

16.

Steel Decking Under Turbine 11 Deck North Extension

17.

Degraded Grid Voltage Modifications 11 Evaluations Due Date

1. Wide Range Gas Monitor Plate-Out Cycle 9

2. Condensate Storage Tank Flooding Potential Cycle 9

3. Automatic Trip of Reactor Coolant Pumps Cycle 9

4.

Inadequate Core Cooling Instrumentation Cycle 9

5. Regulatory Guide 1.97 Comparison December 16, 1985

6.

Safety Parameter Display System January 1, 1987

7.

Control Room Design Review May 1, 1987

8.

Revision of System Descriptions Cycle 10 SCHEDULE C Southern California Edison Company initiated plant betterment projects. These projects are scheduled as indicated.

Several projects do not yet have schedules set as these will be determined by resource availability.

As indicated in the Plan, this schedule of projects is provided for information only in order to understand the totality of work scheduled for implementation at SONGS 1. SCE may at any time and without NRC notification make changes deemed necessary in this schedule as provided in the Plan.

Current Implementation Description Schedule

1. Add Rubber Shock Absorbing Equipment to Fuel Crane 9

for Limiting of Travel

2.

Domestic Water Tie-in Replacement 9

3.

800 MHZ Radio System for Improved Plant Communications 9

-5 Current Implementation Description Schedule

4.

Provide Grounding for the Rebar in the Unit 1 Intake 9

Structure

5. Replace Diesel Generator Indicating Lights with 9

Resistance Types

6.

Relocate the OES Alarm Circuit from the ORMS 1214 9

Circuit to the WRGM 1254

7.

Review the Adequacy of the Platform with Respect to 9

Personnel Safety for Permanent use in Containment

8.

Determine Feasibility of Installing Steam Generator 9

Manway Tensioners

9. Study Radiation Monitoring System Replacement 9

10.

Install Flow Orifice in the Minimum Flow Line for 9

the Charging Pumps, and Install Flange for Pipe Cap Replacement vs. Rewelding

11.

Provide Various Control Room Upgrades to Improve the 9

Physical Environment of the Control Room and Performance of the Operators

12.

Install a Safety Cage on the North Ladder Which 9

Provides the Access to the Reactor Cavity from the Operating Deck

13.

Upgrade the North Circulating Water Pump Embedded 9

Mounting Support Bolts

14.

Provide a Test Switch Assembly to Replace the Existing 9

Switches in the Safeguard Load Sequencing System

15.

Replace Instrument Control Racks 1-5 10

16.

Replace the Unit 1 Excore Nuclear Instrumentation 10

17.

Modify the Generator and Auxiliary Transformer 10 Metering Circuits to Upgrade to Billing Standards Required by the Participants

18. Master Specialties Switch Modifications 10

19.

Study Moisture Separator Reheater Control Scheme to 10 Improve Temperature Control During Reheat Warmup

-6 Current Implementation Description Schedule

20.

Extend the Air Ejector Discharge Line 15 Feet up the 10 Vent Stack to Eliminate Backflow in the Line Caused by the Vent Fan Discharge Air

21.

Synchro Check Relay Protection NS1

22.

Add Drain Valves on the Bypass Lines at the Feedwater NS Flow Control Station

23.

Traveling Screen Bearing Wash:

Remove and Replace NS Service Water Pipe

24.

Install Line from the Unit 2/3 Demin System Tie-in NS Point to the Unit 1 AFW Storage, Primary Plant Makeup, and Condensate Storage Tank

25.

Condenser and Primary Plant Storage to Demin Tie In NS

26.

Install a Protective Cover Over the Unit 1 Turbine NS Gantry Crane Trolley

27.

Install Proximity Probe Vibration Detectors at the NS Turbine Generator Bearings

28.

Temperature Indication for Heat Trace NS

29.

Various Tsunami Pit Upgrades (Remove Retired Equipment, NS and Install Handrails)

30.

Relocate Turbine Deck Fencing to Ground Level Fencing NS

31.

Install Ping 3-B Portable Radiation Monitor for Unit 1 NS

32.

Relocate Transmitters Outside of Hold Up Tank Rooms NS and Provide Blowback Taps for Sensing Lines

33.

Modify and Replace Existing Process Chemical NS Instrumentation and Analyzers

34.

Upgrade the Agastat D.C. Relay Circuit Utilized for NS the Containment Isolation System

35.

Redesign the Signal System (Float System) to Reduce NS the Effect on the Sump Level Fluid Monitoring Due to Buildup of Sludge in the Sump and also Eliminate Excessive Cycling of the Sump Pump Motor

-7 Current Implementation Description Schedule

36.

Install a Permanent Walkway Located Under the Operating NS Deck Inside the Sphere to Permit Access to Fire Detectors XA297, XA297A, XA298, XA299, XA 301, and XA 302

37.

Modify the No. 2 Sequencer to Eliminate the Erroneous NS Reset Indication.

This Involves Modifying the Logic Cards and the Safety Injection Reset Indication

38.

Installation of a Sampling Point for Taking Samples of NS Cooling Jacket Water on the Unit 1 Diesel Generator

39.

Modify the High Turbine Lube Oil Reservoir to Install a NS Three Way Dump Valve at the Turbine Lube Oil Reservoir to Mitigate the Fuel Source in a Fire Situation Associated with Control Oil Line Failure

40.

Replace Masoneilan Type Containment Isolation Valves NS

41.

Relocate the Diesel Generator Starting Air Piping to NS Reduce Physical Obstructions that are Hazardous to Personnel Working in the Vicinity of the Diesels

42.

Upgrade the PORV Actuators (CV 545 and 546) to Allow NS the Diaphram to Withstand Normal Instrument Air Pressure and Remove the Cashco Regulators

43.

Provide Monitoring for the RCP Motor Stator Temperature NS Utilizing the Plant Computer

44.

Door Closure Modification 480V and 4kV Rooms NS

45.

Redesign Baling Room, Install Ventilated Table, and NS Chain Fall for Moving Drums (Solid Radwaste Handling Method Study)

46.

Install Removable Panels Below Smoke Detectors in NS Fire Zones 6 and 7, or Modify Ceiling Panels to be Removable

47.

Upgrade the Barksdale Process Switches on the Unit 1 NS Diesel Generators to Mitigate Loss of Starting Air Pressure

48.

Install Lighting in the Area Outside the 480 Volt Room, NS Near the Halon Bottles

0I

-8 Current Implementation Description Schedule

49.

Boric Acid Heat Trace Alarms Separation NS

50.

Upgrade the Locking Devices and Install Indicating NS Devices on Manual Valves

51.

Install 4 Telephone Accoustical Booths in the High NS Noise Areas of the Unit 1 Protected Area

54.

Replace the Reactor Cycle Sampling Valve SV-3302 With NS a Masoneilan Model 8100 Pneumatic Control Valve

55.

Remove Flash Evaporator Section of E9-A and E9-B NS Except the Condenser Tubes 1

"NS" indicates schedule has not been established. These projects will be completed as resources become available.

GEH:4793F