TMI-09-064, Updated Appendix A.5 License Renewal Commitment List

Updated Appendix A.5 License Renewal Commitment List

ML091530105
Person / Time
Site:	Crane
Issue date:	05/29/2009
From:	Gallagher M Exelon Generation Co, Exelon Nuclear
To:	Document Control Desk, NRC/FSME
References
TMI-09-064
Download: ML091530105 (17)

Text

Exekrn.

Michael P. GallagheT, PE Vice President License Renewal Projects Telephone 610.765.5958 www.exeloncorp.com michaelp.gallagher@exe]oncorp.com Nuclear 10 CFR 54 10 CFR 50 Exelon Nuclear 2oo Exelon Way KSA/2-E Kennett Square, PA 19348 TMI-09-064 May 29, 2009 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555 Three Mile Island Nuclear Station, Unit 1 Facility Operating License No. DPR-50 NRC Docket No. 50-289

References:

Three Mile Island Nuclear Station, Unit 1 updated Appendix A.5 License Renewal Commitment List.

1. Letter from M. Gallagher (EGC) to U. S. Nuclear Regulatory Commission, "Future Correspondence Concerning the License Renewal Application of Three Mile Island, Unit 1, and a Revision to the License Renewal Commitment List," dated January 26, 2009.

2. Letter from B. Holian (U. S. Nuclear Regulatory Commission) to M. Gallagher Exelon Generation Company, "Safety Evaluation Report With Open Items related to the license renewal of Three Mile Island Nuclear Station, Unit 1,"

dated March 13, 2009.

In the Reference 1 letter, Exelon Generation Company (EGC) submitted an updated Appendix A.5 License Renewal Commitment List.

In the Reference 2 letter, the U. S. Nuclear Regulatory Commission (USNRC) requested EGC to review the "Safety Evaluation Report with Open Items Related to the License Renewal of Three Mile Island Nuclear Station, Unit 1." During the EGC review, it was identified that a wording change was required to Appendix A.5 License Renewal Commitment List, Table item #

28, along with minor changes to further clarify the implementation schedule. The revised Appendix A.5 License Renewal Commitment List is contained in Attachment A to this letter.

If you have any questions, please contact Al Fulvio, Manager License Renewal, at 610-765-5936.

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May 29, 2009 Page 2 of 2 TMI-09-064 I declare under penalty of perjury that the foregoing is true and correct.

Respectfully, Executed on d5-2--Uo Michael ýP.Gallagher Vice President, License Renewal Exelon Generation Company, LLC Attachment A: EGC correction to TMI-1 License Renewal Commitment List A.5.

cc:

Regional Administrator, USNRC Region I, w/ Attachment USNRC Project Manager, NRR - License Renewal, Safety, w/ Attachment USNRC Project Manager, NRR - License Renewal, Environmental, w/o Attachment USNRC Project Manager, NRR - TMIGS, w/o Attachment USNRC Senior Resident Inspector, TMIGS, w/o Attachment File No. 08001

Attachment - A May 29, 2009 Page 1 of 15 TMI-09-064 Attachment - A Note: New text will be shown as bolded italics.

EGC correction to TMI-1 License Renewal Commitment List A.5

Attachment - A May 29, 2009 Page 2 of 15 TMI-09-064 A.5 License Renewal Commitment List UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

1.

ASME Section XI Inservice Existing program is credited.

A.2.1.1 Ongoing Section Inspection, Subsections IWB, B.2.1.1 IWC, and IWD

2.

Water Chemistry Existing program is credited.

A.2.1.2 Prior to the period of Section extended operation.

B.2.1.2 The program will be enhanced to incorporate the continuous monitoring of sodium in steam generator blowdown, making it consistent with EPRI 1008224, Pressurized Water Reactor Secondary Water Chemistry Guidelines, Revision 6.

3.

Reactor Head Closure Studs Existing program is credited.

A.2.1.3 Prior to the period of Section extended operation.

B.2.1.3 The program will be enhanced to select an alternate stable lubricant that is compatible with the fastener material and the Letter 5928-environment.

08-20208 dated 10/30/2008

4.

Boric Acid Corrosion Existing program is credited.

A.2.1.4 Ongoing Section B.2.1.4

5.

Nickel-Alloy Penetration Existing program is credited.

A.2.1.5 Ongoing Section Nozzles Welded to the Upper B.2.1.5 Reactor Vessel Closure Heads of Pressurized Water Reactors

6.

Flow-Accelerated Corrosion Existing program is credited.

A.2.1.6 Ongoing Section B.2.1.6

7.

Bolting Integrity Existing program is credited.

A.2.1.7 Ongoing Section B.2.1.7

8.

Steam Generator Tube Existing program is credited.

A.2.1.8 Ongoing Section Integrity B.2.1.8

Attachment - A May 29, 2009 Page 3 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

9.

Open-Cycle Cooling Water Existing program is credited.

A.2.1.9 Prior to the period of Section System extended operation.

B.2.1.9 The program will be enhanced by adding a new river water chemical treatment system to treat the river water systems for biofouling.

10.

Closed-Cycle Cooling Water Existing program is credited.

A.2.1.10 Program and one-Section System time inspections to B.2.1.10 The program will be enhanced to include a one-time inspection be implemented of selected components in stagnant flow areas to confirm the prior to the period absence of aging effects resulting from exposure to closed of extended cycle cooling water. Also, a one-time inspection of selected operation.

CCCW chemical mix tanks and associated piping components will be performed to verify corrosion has not occurred on the interior surfaces of the tanks and associated piping components.

11.

Inspection of Overhead Existing program is credited.

A.2.1.11 Prior to the period of Section Heavy Load and Light Load extended operation.

B.2.1.11 (Related to Refueling)

The program will be enhanced to include visual inspection of Handling Systems rails in the rail system for loss of material due to wear, and visual inspection of structural bolting for loss of material.

Acceptance criteria will be enhanced to require that significant loss of material due to wear will be evaluated or corrected to ensure the intended function of the crane or hoist is not impacted.

12.

Compressed Air Monitoring Existing program is credited.

A.2.1.12 Prior to the period of Section extended operation.

B.2.1.12 The program will be enhanced to include air quality testing for dew point, particulates, lubricant content, and contaminants to ensure that the contamination standards of ANSI/ISAS7.0.01-1996, paragraph 5 are met. In addition the program will be enhanced to include air quality sampling on a representative sampling of headers on a yearly basis in accordance with the guidelines of ASME OM-S/G-1998, Part 17 and EPRI TR-108147.

Attachment - A May 29, 2009 Page 4 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

13.

Fire Protection Existing program is credited.

A.2.1.13 Prior to the period of Section extended operation.

B.2.1.13 The program will be enhanced to include additional inspection criteria for degradation of fire barrier walls, ceilings, and floors, Letter 5928-and specific fuel supply line inspection criteria for diesel-driven 08-20204 fire pumps during tests.

dated In addition, implementing surveillance procedures for halon and 10/20/2008 carbon dioxide suppression systems will specifically require inspection for corrosion, mechanical damage or damage to dampers, and will include acceptance criteria stating that detected signs of corrosion or mechanical damage be evaluated, with corrective action taken as appropriate.

14.

Fire Water System Existing program is credited.

A.2.1.14 Prior to the period of Section extended operation.

B.2.1.14 The program will be enhanced to include sprinkler head testing in accordance with NFPA 25, "Inspection, Testing and Inspection schedule Maintenance of Water-Based Fire Protection Systems."

identified in Samples will be submitted to a testing laboratory prior to being commitment.

in service 50 years. This testing will be repeated at intervals not exceeding 10 years.

Prior to the period of extended operation, the program will be enhanced to include periodic non-intrusive wall thickness measurements of selected portions of the fire water system at an interval not to exceed every 10 years. The initial wall thickness inspections will be performed prior to the period of extended operation.

Attachment - A May 29, 2009 Page 5 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

15.

Aboveground Steel Tanks Existing program is credited.

A.2.1.15 Program and one-Section time inspections to B.2.1.15 The program will be enhanced to include one-time thickness be implemented measurements of the bottom of the Condensate Storage prior to the period Tanks, which are supported on concrete foundations. The of extended measurements will be taken to ensure that significant operation.

degradation is not occurring and the component intended function will be maintained during the extended period of operation. The program will also be enhanced to inspect the sealant at the tank-foundation interface.

16.

Fuel Oil Chemistry Existing program is credited.

A.2.1.16 Program and one-Section time inspections to B.2.1.16 The program will be enhanced to include:

be implemented The analysis of new fuel oil for specific or API gravity, prior to the period kinematic viscosity, and water and sediment prior to of extended filling the fuel oil storage tanks followed by full operation.

spectrum analysis within 31 days after the addition of the fuel oil into the fuel oil storage tanks.

The determination of water and sediment and particulate contamination in accordance with ASTM standards.

The analysis for bacteria in new and stored fuel oil.

The addition of biocides, stabilizers, or corrosion inhibitors as determined by fuel oil analysis activities.

Activities to periodically drain water and sediment from tank bottoms, and, activities to periodically drain, clean, and inspect fuel oil tanks.

Manual sampling in accordance with ASTM standards and required frequencies:

The use of ultrasonic techniques for determining tank bottom thicknesses should there be any evidence of loss of material due to general, pitting, crevice, and microbiologically influenced corrosion, and fouling found during visual inspection activities.

To confirm the absence of any significant aging

Attachment - A May 29, 2009 Page 6 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A) effects, one-time inspections will be performed on the following tanks:

Station Blackout Diesel Clean Fuel Tank Station Blackout Diesel Day Tank

17.

Reactor Vessel Surveillance Existing program is credited.

A.2.1.17 Prior to the period of Section extended operation.

B.2.1.17 The program will be enhanced to address maintenance of the TMI-1 cavity dosimetry exchange schedule. The program will also be enhanced to clarify that, if future plant operations exceed the limitations or bounds specified in Regulatory Position 1.3 of RG 1.99, Rev. 2, the impact of plant operation changes on the extent of reactor vessel embrittlement will be evaluated and the NRC will be notified.

18.

One-Time Inspection Program is new.

A.2.1.18 Program and one-Section time inspections to B.2.1.18 The program will be used to provide reasonable assurance that be implemented an aging effect is not occurring, or that the aging effect is prior to the period occurring slowly enough to not affect a components intended of extended function during the period of extended operation, and therefore operation.

will not require additional aging management. The program will be credited for cases where either (a) an aging effect is not expected to occur but there is insufficient data to completely rule it out, (b) an aging effect is expected to progress very slowly in the specified environment, but the local environment may be more adverse than that generally expected, or (c) the characteristics of the aging effect include a long incubation period.

This program will be used for the following:

To confirm the effectiveness of the Water Chemistry program to manage the loss of material, cracking, and the reduction of heat transfer aging effects for steel, stainless steel, copper alloy, nickel alloy, and aluminum alloy in treated water, steam, and reactor coolant environments.

Attachment - A May 29, 2009 Page 7 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

To confirm the effectiveness of the Fuel Oil Chemistry program to manage the loss of material aging effect for steel, stainless steel, and copper alloy in a fuel oil environment.

To confirm the effectiveness of the Lubricating Oil Analysis program to manage the loss of material and the reduction of heat transfer aging effects for steel, stainless steel, copper alloy, and aluminum alloy in a lubricating oil environment.

To confirm the loss of material aging effect is insignificant for stainless steel and copper alloy in an air/gas - wetted environment.

Inspection methods will include visual examination or volumetric examinations. Acceptance criteria will be in accordance with industry guidelines, codes, and standards.

The One-Time Inspection program provides for the evaluation of the need for follow-up examinations to monitor the progression of aging if age-related degradation is found that could jeopardize an intended function before the end of the period of extended operation. Should aging effects be detected, the program triggers actions to characterize the nature and extent of the aging effect and determines what subsequent monitoring is needed to ensure intended functions are maintained during the period of extended operation.

19.

Selective Leaching of Program is new.

A.2.1.19 Program and one-Section Materials time inspections to B.2.1.19 The program will be used to manage the loss of material due to be implemented selective leaching. The program includes inspection of a prior to the period representative sample of susceptible components to determine of extended if loss of material due to selective leaching is occurring.

operation.

One-time inspections will include visual examinations, supplemented by hardness tests, and other examinations, as required. If selective leaching is found, the condition will be evaluated to determine the need to expand inspection scope.

Attachment - A May 29, 2009 Page 8 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

20.

Buried Piping and Tanks Existing program is credited.

A.2.1.20 Prior to the period of Section Inspection extended operation.

B.2.1.20 The program will be enhanced to include:

Inspection of buried stainless steel piping and Inspection schedule components prior to entering the period of extended identified in operation.

commitment.

Inspection of buried cast iron, carbon steel, concrete-coated carbon steel, and stainless steel piping and components within ten years after entering the period of extended operation.

Internal inspection and UT of the D.G. Fuel Storage 30,000 Gallon Tank prior to the period of extended operation, and within ten years after entering the period of extended operation

21.

External Surfaces Monitoring Program is new.

A.2.1.21 Prior to the period of Section extended operation.

B.2.1.21 The program will be used to manage aging effects through visual inspection of external surfaces for evidence of hardening and loss of strength and loss of material. The program directs visual inspections that are performed during system walkdowns. The program consists of periodic visual inspection of components such as piping, piping components, ducting, and other components within the scope of license renewal.

Visual inspections may be augmented by physical manipulation to detect hardening and loss of strength of elastomers.

Attachment - A May 29, 2009 Page 9 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

22.

Inspection of Internal Program is new.

A.2.1.22 Prior to the period of Section Surfaces in Miscellaneous extended operation.

B.2.1.22 Piping and Ducting The program will be used to manage cracking due to stress Components corrosion cracking; hardening and loss of strength due to Letter 5928-elastomer degradation; loss of material due to general, pitting, 08-20204 crevice, and microbiologically influenced corrosion, erosion, dated and fouling; and reduction of heat transfer due to fouling. The 10/20/2008 program includes provisions for visual inspections of the internal surfaces and volumetric testing of components not managed under any other aging management program.

Visual inspections may be augmented by physical manipulation to detect hardening and loss of strength of elastomers.

23.

Lubricating Oil Analysis Existing program is credited.

A.2.1.23 Ongoing Section B.2.1.23

24.

ASME Section XI, Subsection Existing program is credited.

A.2.1.24 Ongoing Section IWE B.2.1.24

25.

ASME Section Xl, Subsection Existing program is credited.

A.2.1.25 Ongoing Section IWL B.2.1.25

26.

ASME Section Xl, Subsection Existing program is credited.

A.2.1.26 Ongoing Section IWF 13.2.1.26

27.

10 CFR Part 50, Appendix J Existing program is credited.

A.2.1.27 Ongoing Section 13.2.1.27

28.

Structures Monitoring Existing program is credited.

A.2.1.28 Prior to the period of Section Program The program will be enhanced to include:

extended operation.

B.2.1.28 Service Building UPS Diesel Building Mechanical Draft Cooling Tower Structures Miscellaneous Yard Structures:

o Storm Drainage and Flood Control Structure, including the structural platform o

Duct banks o

Manholes o

Foundations for:

a Condensate Storage Tank

Attachment - A May 29, 2009 Page 10 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

Borated Water Storage Tank, including the Borated Water Storage Tank tunnel Altitude Tank Emergency Diesel Fuel Oil Storage Tank Penetration seals which perform a License Renewal intended function for an in-scope structure.

Monitoring of the Intake Canal for loss of material and loss of form.

Monitoring of electrical panels, junction boxes, instrument panels, and conduits for loss of material due to corrosion.

Monitoring of ground water chemistry by periodically sampling, testing, and analysis of ground water to confirm that the environment remains non-aggressive for buried reinforced concrete.

Monitoring of reinforced concrete submerged in raw water associated with Intake Screen and Pumphouse, Circulating Water Pump House, Mechanical Draft Cooling Tower Structures, Natural Draft Cooling Tower Basins, and Circulating Water Tunnel.

Monitoring of vibration isolators, associated with component supports other than those covered by ASME X1, Subsection IWF, for reduction or loss of isolation function.

Monitoring of HVAC duct supports for loss of material.

Parameters monitored will be enhanced to include plausible aging effects and mechanisms.

Monitoring of concrete structures for a reduction in anchor capacity due to local concrete degradation.

This will be accomplished by visual inspection of concrete surfaces around anchors for cracking, and spalling.

Revised acceptance criteria to provide details

Attachment - A May 29, 2009 Page 11 ofl15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A) specified in A CI 349.3R-96.

29.

Protective Coating Monitoring Existing program is credited.

A.2.1.29 Ongoing Section and Maintenance Program B.2.1.29

30.

Electrical Cables and Program is new.

A.2.1.30 Program and first Section Connections Not Subject to inspections to be B.2.1.30 10 CFR 50.49 Environmental The program will be used to manage aging of non-EQ cables implemented prior Qualification Requirements and connections during the period of extended operation. A to the period of representative sample of accessible cables and connections extended operation.

located in adverse localized environments will be visually inspected at least once every 10 years for indications of accelerated insulation aging such as embrittlement, discoloration, cracking, or surface contamination. An adverse localized environment is a condition in a limited plant area that is significantly more severe than the specified service

______________________environment for the cable or connection.

31.

Electrical Cables and Existing program is credited.

A.2.1.31 Program, first tests Section Connections Not Subject to and calibrations, B.2.1.31 10 CFR 50.49 Environmental The program will be enhanced to manage the aging of the and first Qualification Requirements cable and connection insulation of the in scope radiation assessment of Used in Instrumentation monitoring and nuclear instrumentation circuits in the Radiation calibration results Circuits Monitoring and Nuclear Instrumentation and Incore Monitoring to be implemented Systems. The in scope radiation monitoring and nuclear prior to the period instrumentation circuits are sensitive instrumentation circuits of extended with low-level signals and are located in areas where the operation.

cables and connections could be exposed to adverse localized environments caused by heat, radiation, or moisture. These adverse localized environments can result in reduced insulation resistance causing increases in leakage currents. Calibration testing and performance monitoring are currently being performed for in scope radiation monitoring circuits. Direct cable testing will be performed as an enhancement to ensure that the cable and connection insulation resistance is adequate for the nuclear instrumentation circuits to perform their intended functions.

Attachment - A May 29, 2009 Page 12 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

32.

Inaccessible Medium Voltage Program is new.

A.2.1.32 Program and first Section Cables Not Subject to 10 tests and B.2.1.32 CFR 50.49 Environmental The program will be used to manage the aging effects and inspections to be Qualification Requirements mechanisms of non-EQ, in scope inaccessible medium voltage implemented prior Letter 5928-cables. These cables may at times be exposed to significant to the period of 08-20208 moisture simultaneously with significant voltage. The TMI-1 extended operation. dated cables in the scope of this aging management program will be 10/30/2008 tested using a proven test for detecting deterioration of the insulation system due to wetting, such as power factor, partial discharge, or polarization index, as described in EPRI TR-103834-P1-2, or other testing that is state-of-the-art at the time the test is performed. The cables will be tested at least once every 10 years. Manholes associated with the cables included in this aging management program will be inspected for water collection, initially at least twice a year, in accordance with existing practices, and drained as required. The frequency will be adjusted based on inspection results recognizing that the objective of the inspections, as a preventive action, is to keep the cables infrequently submerged, thereby minimizing their exposure to significant moisture. The maximum time between inspections will be 2 years, which is in alignment with the recommended frequency in the NUREG-1801 AMP XI.E3.

Attachment - A May 29, 2009 Page 13 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

33.

Metal Enclosed Bus Existing program is credited.

A.2.1.33 Program and first Section inspections and B.2.1.33 The program will be enhanced to include the following tests to be inspection criteria:

implemented prior The internal portion of the metal enclosed bus will be to the period of visually inspected for cracks, corrosion, foreign debris, extended operation.

excessive dust build-up and evidence of moisture intrusion.

The bus insulation will be visually inspected for signs of embrittlement, cracking, melting, swelling, or discoloration, which may indicate overheating or aging degradation.

The internal bus supports will be visually inspected for structural integrity and signs of cracks.

The program will also be enhanced to perform internal visual inspections on the 480V Metal Enclosed Bus and the Station Black Out Metal Enclosed Bus.

34.

Electrical Cable Connections Program is new.

A.2.1.34 Program and one-Section Not Subject to 10 CFR 50.49 time testing to be B.2.1.34 Environmental Qualification The program will be used to manage the aging effects of implemented prior Requirements metallic parts of non-EQ electrical cable connections within the to the period of scope of license renewal during the period of extended extended operation.

operation. A representative sample of non-EQ electrical cable connections will be selected for one-time testing considering application (medium and low voltage), circuit loading (high loading) and location, with respect to connection stressors.

The technical basis for the sample selected is to be documented. The specific type of test performed will be a proven test for detecting loose connections, such as thermography or contact resistance measurement, as appropriate to the application.

Attachment - A May 29, 2009 Page 14 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

35.

Nickel Alloy Aging Existing program is credited.

A.2.2.1 Ongoing Section Management Program B.2.2.1 TMI-1 commits to implement applicable Bulletins, Generic Letters, and staff-accepted industry guidelines.

36.

PWR Vessel Internals TMI-1 commits to the following activities for the PWR Vessel N/A Prior to the period of N/A Internals program:

extended operation.

Participate in the industry programs for investigating and managing aging effects on reactor internals.

Evaluate and implement the results of the industry programs as applicable to the reactor internals.

Upon completion of these programs, but not less than 24 months before entering the period of extended operation, submit an inspection plan for reactor internals to the NRC for review and approval.

37.

Metal Fatigue of Reactor Existing program is credited.

A.3.1.1 Prior to the period of Section Coolant Pressure Boundary extended operation.

B.3.1.1 The program will be enhanced to add the statement:

"Acceptable corrective actions include: reanalysis of the component to demonstrate that the design code limit will not be exceeded prior to or during the period of extended operation; repair of the component; replacement of the component, or other methods approved by the NRC." In addition, the program will be enhanced to require a review of additional reactor coolant pressure boundary locations if the usage factor for one of the environmental fatigue sample locations approaches its design limit.

38.

Concrete Containment Existing program is credited.

A.3.1.2 Ongoing Section Tendon Prestress B.3.1.2

39.

Environmental Qualification Existing program is credited.

A.3.1.3 Ongoing Section (EQ) of Electrical B.3.1.3 Components

40.

Steam Generators Install new Once Through Steam Generators (OTSGs) prior to N/A Prior to the period of N/A I

I the period of extended operation.

II extended operation.

Attachment - A May 29, 2009 Page 15 of 15 TMI-09-064 UFSAR Supplement Enhancement or No.

Program or Topic Commitment Location Implementation Source (LRA Schedule Appendix A)

41.

New P-T Curves Revised pressure-temperature (P-T) limits and low-temperature A.4.2.5 Prior to the period of Section 4.2.5 overpressurization (LTOP) limits for a 60-year operating life extended operation or have been prepared and will be submitted to the NRC for prior to exceeding 29 approval.

EFPY, whichever comes first.

42.

Containment Liner Repair Prior to the period of extended operation, TMI-1 will restore the N/A Prior to the period of Letter 5928-Reactor Building liner to its nominal plate thickness by weld extended operation.

08-20208 repair for the previously identified corroded areas of the dated Reactor Building liner where the thickness of the base metal is 10/30/2008 reduced by more than 10% of the nominal plate thickness.

43.

Boral Test Coupon Boral test coupon surveillance will continue through the period N/A Ongoing Letter 5928-Surveillance of extended operation.

08-20229 dated 11/12/2008