"Draft Meeting" is not in the list (Request, Draft Request, Supplement, Acceptance Review, Meeting, Withholding Request, Withholding Request Acceptance, RAI, Draft RAI, Draft Response to RAI, ...) of allowed values for the "Project stage" property.

Text

Draft of Traveler TSTF-577, Revised Frequencies for Steam Generator Tube Inspections, for May 2020 Presubmittal Meeting
	ML20113E848
Person / Time
Site:	Technical Specifications Task Force
Issue date:	04/22/2020
From:	; Technical Specifications Task Force
To:	; Office of Nuclear Reactor Regulation
	Honcharik M, 301-415-1774, NRR/DSS
References
	PWROG-6, Rev. 0, TSTF-577, Rev. 0
	Download: ML20113E848 (81)
	v • d • e

TSTF-577, Rev. 0 PWROG-6, Rev. 0 NUREGs Affected:

Revised Frequencies for Steam Generator Tube Inspections Technical Specifications Task Force Improved Standard Technical Specifications Change Traveler 1430 1431 1432 1433 1434 Classification: 1) Technical Change Recommended for CLIIP?: Yes Correction or Improvement:

Improvement NRC Fee Status:

Not Exempt Benefit:

Reduces Testing Changes Marked on ISTS Rev 4.0 2194 PWROG RISD & PA (if applicable): RS-2018-023,PA-LSC-1649 See attached.

Revision History Affected Technical Specifications OG Revision 0 Revision Status: Active Original Issue Revision

Description:

Revision Proposed by:

EPRI Owners Group Review Information Date Originated by OG:

13-Mar-20 Owners Group Comments (No Comments)

Date: 27-Mar-20 Owners Group Resolution:

Approved TSTF Review Information TSTF Received Date:

13-Mar-20 Date Distributed for Review 13-Mar-20 TSTF Comments:

(No Comments)

Date: 27-Mar-20 TSTF Resolution:

Approved 5.5.9 Steam Generator Program 5.6.7 Steam Generator Tube Inspection Report 30-Mar-20 Copyright(C) 2020, EXCEL Services Corporation. Use by EXCEL Services associates, utility clients, and the U.S. Nuclear Regulatory Commission is granted. All other use without written permission is prohibited.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page i Table of Contents

1.

SUMMARY

DESCRIPTION.............................................................................................. 1

2.

DETAILED DESCRIPTION............................................................................................... 1 2.1.

System Design and Operation.......................................................................................... 1 2.2.

Current Technical Specifications Requirements........................................................... 2 2.3.

Reason for the Proposed Change..................................................................................... 3 2.4.

Description of the Proposed Change............................................................................... 3 2.4.1. TS Based on TSTF-449 versus TSTF-510...................................................................... 3 2.4.2. Revision to the SG Tube Inspection Requirements........................................................ 4 2.4.2.1. Changes for Alloy 600MA Tubing Material.......................................................... 6 2.4.2.2. Changes for Alloy 600TT Tubing Material............................................................ 7 2.4.2.3. Changes for Alloy 690TT Tubing Material............................................................ 8 2.4.2.4. Inspections After Crack Indications are Found.................................................... 10 2.4.3. Revision of the SG Tube Inspection Report Contents.................................................. 11 2.4.4. Editorial Improvements................................................................................................ 12

3.

TECHNICAL EVALUATION.......................................................................................... 13 3.1.

Revision to the SG Tube Inspection Requirements..................................................... 13 3.1.1. Changes to TS Based on TSTF-449 That Were Approved in TSTF-510..................... 13 3.1.2. Alloy 600MA Tubing Material Inspection Frequency................................................. 14 3.1.3. Alloy 600TT Tubing Material Inspection Frequency................................................... 14 3.1.4. Alloy 690TT Tubing Material Inspection Frequency................................................... 15 3.1.5. Inspection After Cracking Indications.......................................................................... 16 3.2.

Revision of the TS SG Tube Inspection Report Contents........................................... 16 3.3.

Editorial Improvements................................................................................................. 17

4.

REGULATORY EVALUATION...................................................................................... 17

5.

REFERENCES.................................................................................................................... 19 Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 1

1.

SUMMARY

DESCRIPTION The Technical Specifications (TS) related to steam generator (SG) tube inspection are revised to extend the surveillance interval for some SG tube types by 24 effective full power months (EFPM) and to revise the post-inspection reporting requirements. The proposed change modifies NUREG-1430, "Standard Technical Specifications - Babcock & Wilcox Plants," NUREG-1431, "Standard Technical Specifications - Westinghouse Plants," and NUREG-1432, "Standard Technical Specifications - Combustion Engineering Plants."

2.

DETAILED DESCRIPTION 2.1.

System Design and Operation The SG tubes in pressurized water reactors (PWRs) have a number of important safety functions.

SG tubes are an integral part of the reactor coolant pressure boundary (RCPB) and, as such, are relied on to maintain the primary systems pressure and inventory. As part of the RCPB, the SG tubes are unique in that they act as a heat transfer surface between the primary and secondary systems to remove heat from the primary system. In addition, the SG tubes isolate the radioactive fission products in the primary coolant from the secondary system.

The steam generator tube rupture (SGTR) accident is the limiting design basis event for an SG.

The analysis of an SGTR event assumes a bounding primary to secondary leakage rate equal to the operational leakage rate TS limit, plus the leakage rate from a double-ended rupture of a single tube. The analysis for design basis accidents and transients other than an SGTR assume the SG tubes retain their structural integrity (i.e., they are assumed not to rupture). In these analyses, the steam discharge to the atmosphere is based on the total primary to secondary leakage from all SGs or is assumed to increase to the limit as a result of accident induced conditions. For accidents that do not involve fuel damage, the primary coolant activity level is assumed to be equal to the TS limits. For accidents that assume fuel damage, the primary coolant activity is a function of the amount of activity released from the damaged fuel.

SG tube integrity is necessary to ensure the tubes are capable of performing their intended safety functions. Concerns relating to the integrity of the tubing stem from the fact that the SG tubing can be subject to a variety of degradation mechanisms. SG tubes have experienced tube degradation related to corrosion phenomena, such as wastage, pitting, intergranular attack, and stress corrosion cracking, along with other mechanically induced phenomena such as wear.

These degradation mechanisms can impair tube integrity if they are not managed effectively.

When the degradation of the tube wall reaches a prescribed criterion for action, the tube is considered defective and corrective action is taken, such as plugging or repair. Note that not all plants have approved repair techniques. Therefore, references to "repair" are bracketed in the Standard Technical Specifications.

The industry, working through the Electric Power Research Institute (EPRI) Steam Generator Management Program (SGMP), has implemented a generic approach to managing SG performance referred to as "Steam Generator Degradation Specific Management" (SGDSM).

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 2 The overall program is described in NEI 97-06, "Steam Generator Program Guidelines," which is supported by a number of EPRI guidelines, such as:

PWR Steam Generator Examination Guidelines

Steam Generator Integrity Assessment Guidelines

Steam Generator In-Situ Pressure Test Guidelines

PWR Primary-to-Secondary Leak Guidelines

PWR Primary Water Chemistry Guidelines

PWR Secondary Water Chemistry Guidelines NEI 97-06 and the EPRI Guidelines define a comprehensive, performance based approach to managing SG performance.

2.2.

Current Technical Specifications Requirements There are four Standard Technical Specifications requirements related to SG tube inspections.

Standard Technical Specification (STS) 5.5.9, "Steam Generator (SG) Program,"

describes a program that ensures that SG tube integrity is maintained by meeting the three SG performance criteria: structural integrity, accident induced leakage, and operational leakage. The program defines the performance criteria, requires condition monitoring assessments, defines SG tube plugging or repair criteria, and requires SG inspections.

The SG Program provides inspection frequencies based on SG tube material type Thermally Treated Alloy 690 (i.e., 690TT), Thermally Treated Alloy 600 (i.e. 600TT),

and Mill Annealed Alloy 600 (i.e., 600MA). The SG Program also specifies inspection periods in which 100% of the tubes are required to be inspected.

STS 3.4.13, "RCS [Reactor Coolant System] Operational LEAKAGE," describes the SG operational leakage limit of 150 gallons per day primary to secondary leakage through any one SG.

NUREG-1430 STS 3.4.17, NUREG-1431 STS 3.4.20, and NUREG-1432 STS 3.4.18, "Steam Generator (SG) Tube Integrity," require testing per the Steam Generator Program and provide actions when the SG tube integrity is not maintained.

STS 5.6.7, "Steam Generator Tube Inspection Report," describes a report that is submitted to the NRC within 180 days after entry into Mode 4 following completion of an SG inspection performed per Specification 5.5.9 and describes the results of the inspection.

The plant-specific Technical Specification requirements may vary from the STS.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 3 2.3.

Reason for the Proposed Change Operating experience supports a longer inspection period for plants with 600TT and 690TT tubes. In addition, the current inspection practices permit a simplified inspection routine, with fixed periods for 100% inspection of the SG tubes.

2.4.

Description of the Proposed Change 2.4.1. TS Based on TSTF-449 versus TSTF-510 The current STS requirements were established by TSTF-449, "Steam Generator Tube Integrity,"

approved on May 6, 2005, that:

Established a limit on allowable primary-to-secondary leakage from any one SG,

Revised the SG Program to describe SG condition monitoring, performance criteria, repair methods, repair criteria, and inspection frequency,

Revised the requirements for the SG Tube Inspection Report, and

Added a SG Tube Integrity Specification.

All operating PWRs adopted TSTF-449. TSTF-449 was incorporated into Revision 3.1 of the STS and is in the current Revision 4 of the STS.

In 2009, the TSTF, supported by EPRI, submitted TSTF-510, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection." The differences between TSTF-449 and TSTF-510 that are relevant to the proposed change are:

TSTF-510 changed the phrase "tube repair" to "tube plugging [or repair]" to be consistent with the treatment of plant-specific repair methods in the SG Program.

TSTF-510 added the option to extend each inspection period up to 3 EFPM to include a SG inspection outage in an inspection period.

TSTF-510 added guidance on prorating SG tube inspection samples.

TSTF-510 made wording changes and minor reporting changes to the Steam Generator Tube Inspection Report.

TSTF-510 included minor wording changes, such as stating, "A degradation assessment" instead of "An assessment of degradation."

TSTF-510 was approved by the NRC on October 27, 2011 and has been adopted by greater than 82% of the applicable plants. TSTF-510 was approved after publication of Revision 4 of the STS, which is the most recent revision.

On March 28, 2012, the TSTF wrote to the NRC that an administrative error had been found in TSTF-510, Revision 2 (Agencywide Documents Access and Management System (ADAMS)

Accession No. ML12088A082). One of the editorial improvements in TSTF-510-A revised references to "tube repair criteria" to "tube plugging [or repair] criteria." Not all plants have approved tube repair criteria, so references to tube repair are bracketed to indicate they are plant-specific. In paragraph d.2 (all versions), the TSTF determined one instance of "tube repair criteria" was inadvertently not changed to "tube plugging [or repair] criteria." In a letter dated Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 4 June 17, 2013 (ADAMS Accession No. ML13120A541), the NRC agreed that it was an administrative error and that the correction should be included in license amendment requests to adopt TSTF-510. This correction is included in the proposed changes.

Two sets of STS markups are provided. One set is based on Revision 4 of the STS, which reflects incorporation of TSTF-449. The second set is based on TSTF-510, which has been adopted by the majority of licensees.

In order to maximize the consistency of the proposed TS across the operating fleet, the TSTF-510 changes to the SG Program and the Steam Generator Tube Inspection Report are incorporated into the TSTF-449 markups, such that the proposed TS are the same regardless of the current TS.

In the model application, the licensee will identify whether the current plant TS are based on TSTF-449 or TSTF-510.

2.4.2. Revision to the SG Tube Inspection Requirements The TS Section 5.5.9, paragraph "d" is revised to state:

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging [or repair] criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

REVIEWER'S NOTE--------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing.

The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

[2.

After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 24 effective full power months, which defines the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 5 inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

[2.

After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 72 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated.

The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

[2.

After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 96 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated.

The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 6

3.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall be at the next refueling outage. If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

2.4.2.1. Changes for Alloy 600MA Tubing Material The Paragraph "d.2" for 600MA tubing material is revised.

The requirement to inspect 100% of the tubes every 60 EFPM is replaced with a requirement to inspect 100% of the tubes every 24 EFPM, which is the new inspection period. References to refueling outages are removed.

For TS based on TSTF-449, the allowance to extend the inspection period by 3 months is added.

For TS based on TSTF-510, the discussion of prorating inspections is deleted.

The proposed changes are shown below for TS based on TSTF-449 (insertions are in italics; deletions are struck through).

After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 24 effective full power months, which defines the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage. Inspect 100% of the tubes at sequential periods of 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.

The proposed changes are shown below for TS based on TSTF-510.

After the first refueling outage following SG installation, inspect 100% of the tubes in each steam generator SG at least every 24 effective full power months, which defines the inspection period. or at least every refueling outage (whichever results in more frequent inspections). In addition, inspect 100% of the tubes at sequential periods of 60 effective full power months beginning after the first refueling outage inspection following SG installation. Each 60 effective full power month inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube repair criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 7 fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

2.4.2.2. Changes for Alloy 600TT Tubing Material Paragraph "d.2" for 600TT tubing material is revised.

For TS based on TSTF-510, the requirement to inspect 100% of the tubes during each period in paragraphs d.2.a (120 EFPM), d.2.b (96 EFPM), and d.2.c (72 EFPM) is replaced with a requirement to inspect 100% of the tubes every 72 EFPM, which is the new, fixed inspection period. References to refueling outages are removed.

For TS based on TSTF-449, the requirement to inspect 100% of the tubes at periods of 120, 90, and 60 EFPM is replaced with a requirement to inspect 100% of the tubes every 72 EFPM, which is the new, fixed inspection period. The 48 EFPM limit between inspections is replaced with the 72 EFPM inspection period.

For TS based on TSTF-449, the allowance to extend the inspection period by 3 months is added.

For TS based on TSTF-449, the discussion of prorating inspections is added.

For TS based on TSTF-449, the requirement to inspect 50% of the tubes at the inspection nearest the midpoint of the inspection period is eliminated.

The proposed changes are shown below for TS based on TSTF-449.

After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 72 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage. Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 8 refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.

The proposed changes are shown below for TS based on TSTF-510.

After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 7248 effective full power months, which defines the inspection period. or at least every other refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, and c below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair]

criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

Reviewer's Note ----------------------------------------

A licensee may elect to retain historical and existing inspection period lengths in order to not revise those inspection periods.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 120 effective full power months. This constitutes the first inspection period; b)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; and c)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods.

2.4.2.3. Changes for Alloy 690TT Tubing Material Paragraph "d.2" for 690TT tubing material is revised.

For TS based on TSTF-510, the requirement to inspect 100% of the tubes during each period in paragraphs d.2.a (144 EFPM), d.2.b (120 EFPM), d.2.c (96 EFPM), and d.2.d Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 9 (72 EFPM) is replaced with a requirement to inspect 100% of the tubes every 96 EFPM, which is the new, fixed inspection period. References to refueling outages are removed.

For TS based on TSTF-449, the requirement to inspect 100% of the tubes at periods of 144, 108, 72, and 60 EFPM is replaced with a requirement to inspect 100% of the tubes every 96 EFPM, which is the new, fixed inspection period. The 72 EFPM limit between inspections is replaced with the 96 EFPM inspection period.

For TS based on TSTF-449, the allowance to extend the inspection period by 3 months is added.

For TS based on TSTF-449, the discussion of prorating inspections is added.

For TS based on TSTF-449, the requirement to inspect 50% of the tubes at the inspection nearest the midpoint of the inspection period is eliminated.

The proposed changes are shown below for TS based on TSTF-449.

After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 96 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage. Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.

The proposed changes are shown below for TS based on TSTF-510.

After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 9672 effective full power months, which defines the inspection period. or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 10 If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair]

criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

Reviewer's Note ----------------------------------------

A licensee may elect to retain historical and existing inspection period lengths in order to not revise those inspection periods.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b)

During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

2.4.2.4. Inspections After Crack Indications are Found Paragraph d.3 regarding crack indications is revised.

For TS based on TSTF-510 and TSTF-449, the requirement to inspect within 24 EFPM or one refueling outage after a crack indication is found, whichever is less, is simplified to a requirement to inspect at the next refueling outage.

For TS based on TSTF-449, paragraph d.3 is revised to require inspection of each "affected and potentially affected" SG for the degradation mechanism that caused the crack.

The proposed changes are shown below for TS based on TSTF-449.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall be at the next not exceed 24 effective full power months or one refueling Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 11 outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

The proposed changes are shown below for TS based on TSTF-510.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall be at the next not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

2.4.3. Revision of the SG Tube Inspection Report Contents The Steam Generator Tube Inspection Report for TS based on TSTF-510 and TSTF-449 is revised to include different reporting requirements. The revised report states:

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, "Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;

b.

Nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

Nondestructive examination techniques utilized;

2.

The location, orientation (if linear), measured size (if available),

and voltage response for each indication. For tube wear at support structures that is less than 20 percent through-wall, only the total number of indications needs to be reported;

3.

The results of condition monitoring, including the margin to the tube integrity performance criteria and comparisons to the predicted margin;

4.

Number of tubes plugged [or repaired] during the inspection outage; and Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 12

[5.

Repair method utilized and the number of tubes repaired by each repair method.]

d.

A summary of a forward-looking assessment including the methodology, inputs, and results;

e.

The number and percentage of tubes plugged [or repaired] to date, and the effective plugging percentage in each SG;

f.

The results of any SG secondary side inspections; and

[g.

Insert any plant-specific reporting requirements, if applicable.]

For TS based on TSTF-449 and TSTF-510, the reporting requirements are rearranged. The new reporting requirements are:

A summary of a forward-looking assessment including the methodology, inputs, and results (Item d).

The results of any SG secondary side inspections (Item f).

For TS based on TSTF-449 and TSTF-510, the revised reporting requirements are:

For tube wear at support structures that is less than 20 percent through-wall, only the total number of indications needs to be reported, and the location, orientation (if linear),

measured size (if available), and voltage response is not required to be reported for each such indication (Item c.2).

In addition to the results of condition monitoring, the margin to the tube integrity performance criteria and comparisons to the predicted margin are required to be reported (Item c.3).

When reporting the results of condition monitoring, the results of tube pulls and in-situ testing is not explicitly required to be reported (Item c.3).

Any existing plant-specific reporting requirements are added as Item g.

2.4.4. Editorial Improvements Editorial improvements to the current TS are included. In the introductory paragraph of the "Steam Generator (SG) Program," the second sentence begins "In addition." This phrase is not needed because the first sentence does not establish program requirements. Also, the acronym "SG" is defined in the Steam Generator Program title but is used inconsistently within the program. This is corrected.

A model application is attached. The model may be used by licensees desiring to adopt the traveler following NRC approval.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 13

3. TECHNICAL EVALUATION 3.1.

Revision to the SG Tube Inspection Requirements The existing SG Program contains prescriptive frequencies for inspection of SGs with tubes made of Alloy 600MA, Alloy 600TT, and Alloy 690TT.

3.1.1. Changes to TS Based on TSTF-449 That Were Approved in TSTF-510 The following changes are made to TS based on TSTF-449 to adopt features of TSTF-510.

References to "tube repair criteria" are changed to references to "tube plugging [or repair]

criteria," as not all plants have approved repair criteria.

The proposed change adds an allowance to extend the inspection period by 3 EFPM in order to include a SG inspection outage in an inspection period. The Nuclear Regulatory Commission's (NRC's) model Safety Evaluation (SE) for TSTF-510, available under ADAMS Accession No. ML112101513, determined that the allowance to add up to an additional 3 EFPM potentially impacts the average tube inspection sample size to be implemented during a given inspection in that period. However, the proposed allowance does not impact the required frequency of SG inspection and is, therefore, acceptable.

The proposed change eliminates the requirement to inspect 50% of the tubes at the inspection nearest the midpoint of the inspection period and adds a discussion of prorating inspections.

The NRC's model SE for TSTF-510 noted that if there are not an equal number of inspections in the first half and second half of the inspection period, the average minimum sampling requirement may be markedly different for inspections in the first half of the inspection period compared to those in the second half, even when there are uniform intervals between each inspection. The NRC staff found that there was no basis to require the minimum initial sample size to vary so much from inspection to inspection. TSTF-510 revised the requirement such that the minimum sample size for a given inspection in a given inspection period is 100 percent divided by the number of scheduled inspections during that inspection period. The NRC staff concluded that the change was an improvement over the existing requirement since it provides a more consistent minimum initial sampling requirement.

The proposed change adds two sentences addressing the prorating of required tube sample sizes if a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube repair criteria. The NRC concluded that these sentences were the same as the NRC staff position in Regulatory Information Summary (RIS) 2009-04, Steam Generator Tube Inspection Requirements, dated April 3, 2009 (ADAMS Accession No. ML083470557), Issue 1, and is, therefore, acceptable.

In TSTF-510, paragraph d.3 was revised to require inspection of each "affected and potentially affected" SG for the degradation mechanism that caused the crack. The NRC's Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 14 model SE for TSTF-510 determined that the change was an acceptable clarification of the requirement. The NRC staff stated that intent of the requirement is that it applies to the affected SG and to any other SG which may be potentially affected by the degradation mechanism that caused the known crack(s). If it can be established that the extent of condition of any manufacturing anomaly applies only to one SG and not the others, then the NRC staff agreed that only the affected SG needs to be inspected.

3.1.2. Alloy 600MA Tubing Material Inspection Frequency The TS based on TSTF-449 and TSTF-510 require 100% of the tubes in SGs using Alloy 600MA to be inspected within 60 EFPM and each SG to be inspected at least every 24 EFPM or at least every refueling outage (whichever results in more frequent inspections).

The proposed change requires 100% inspection within 24 EFPM. The change to the inspection frequency is conservative. The prescriptive inspection frequency has not changed, but the requirement to perform 100% inspection is decreased from 60 EFPM to 24 EFPM. This is consistent with current operating practices. As the proposed change results in more frequent 100% inspection (every 24 EFPM instead of every 60 EFPM), the proposed change is acceptable.

For TS based on TSTF-510, the proposed change eliminates the discussion of prorating SG tube inspections. Because the proposed change requires 100% of the tubes to be inspected every 24 EFPM (i.e., every refueling outage), the elimination of the discussion has no effect and is acceptable.

3.1.3. Alloy 600TT Tubing Material Inspection Frequency For TS based on TSTF-510, the current requirement is to inspect 100% of the tubes during each sequential period of 120 EFPM, 96 EFPM, and 72 EFPM, and for TS based on TSTF-449, the current requirement is to inspect 100% of the tubes during each sequential period of 120 EFPM, 90 EFPM, and 60 EFPM. In both cases, each SG must be inspected at least every 48 EFPM or at least every other refueling outage (whichever results in more frequent inspections). The proposed change requires inspecting 100% of the tubes every 72 EFPM regardless of the age of the SGs.

Significant operating experience has been gained over the course of 15 years since the current TS inspection frequencies were determined and provides justification for extending these frequencies.

For the Alloy 600TT fleet, stress corrosion cracking (SCC) is the primary concern. Nine of the seventeen plants with SGs with Alloy 600TT tubing have experienced sporadic cracking. The majority of the cracking has been identified in subpopulations of tubes with anomalous conditions that have been identified and are inspected, as needed, to maintain margin to the performance criteria. Operating experience for nearly forty years has shown no propensity for rapidly increasing crack initiation rates in Alloy 600TT SG tubes, as was observed for Alloy 600MA SG tubes. The proposed change of inspection frequency from 48 EFPM to 72 EFPM has been demonstrated to meet the structural integrity and accident induced leakage performance criteria even for SGs that have experienced cracking. However, the proposed change maintains Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 15 the existing requirement to inspect each affected and potentially affected SG at the next refueling outage after identifying a definitive crack indication. Based on this operating experience, the proposed TS change to require inspection of the tubing every 72 EFPM is acceptable.

Along with the prescribed inspection frequencies in the proposed change, the SG Program requires assessments ensure safe SG inspection intervals that are based on measurable parameters that monitor SG performance, such as results of SG tube inspections and operational leakage. Objective criteria to assess performance are established based on risk insights, deterministic analyses, and performance history. In addition, the TS requirements on operational leakage require a plant shutdown if the limits are exceeded. This ensures that the failure to meet a performance criterion, while undesirable, will not result in an immediate safety concern.

Therefore, the proposed extension of the existing SG inspection frequencies is acceptable.

3.1.4. Alloy 690TT Tubing Material Inspection Frequency For TS based on TSTF-510, the current requirement is to inspect 100% of the tubes during each sequential period of 144 EFPM, 120 EFPM, 96 EFPM, and 72 EFPM, and for TS based on TSTF-449, the current requirement is to inspect 100% of the tubes during each sequential period of 144 EFPM, 108 EFPM, 72 EFPM, and 60 EFPM. In both cases, each SG must be inspected at least every 72 EFPM or at least every third refueling outage (whichever results in more frequent inspections). The proposed change requires inspecting 100% of the tubes every 96 EFPM regardless of the age of the SGs.

Significant operating experience has been gained over the course of 15 years since the current TS inspection frequencies were determined and provides justification for extending these frequencies.

For the Alloy 690TT SGs, wear at support structures is the primary concern. Twenty-one of the forty-four units with Alloy 690TT tubing in the US have few or no structure wear indications.

Fifteen of these have never been required to plug a tube for structure wear. Among these are units that have been in service since the 1990s. The other six units have been required to plug less than 10 tubes for structure wear. Twelve of the units with Alloy 690TT tubing have moderate numbers of wear indications with low growth rates that tend to attenuate over time.

Conservative new initiation and growth rate projections out to 96 EFPM of operating time between inspections for these units has been easily justified, i.e., the structural integrity and accident induced leakage performance criteria are met with margin. The eleven units with Alloy 690TT tubing in the US with higher numbers of wear indications or higher growth rates are limited to inspection frequencies dictated by the assessments required by the SG Program, as is the case with the current inspection frequencies. Based on this operating experience, the TS change to require inspection of the SG tubes at periods not to exceed 96 EFPM is acceptable.

Along with the prescribed inspection frequencies in the proposed change, the SG Program-requires assessments ensure safe SG inspection intervals that are based on measurable parameters that monitor SG performance, such as results of SG tube inspections and operational leakage. Objective criteria to assess performance are established based on risk insights, deterministic analyses, and performance history. In addition, the TS requirements on operational leakage require a plant shutdown if the limits are exceeded. This ensures that the failure to meet Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 16 a performance criterion, while undesirable, will not result in an immediate safety concern.

Therefore, the proposed extension of the existing SG inspection frequencies is acceptable.

3.1.5. Inspection After Cracking Indications The current paragraph d.3 requires inspection within 24 EFPM or one refueling outage after a crack indication is found, whichever is less. References to refueling outages is proposed to be removed from the rest of paragraph d and the current presentation is unnecessarily complex. All PWRs have cycle lengths of 24 months or less and that is not expected to change in the foreseeable future. Therefore, it is acceptable to simplify the requirement to require inspection at the next refueling outage after a crack is found.

3.2.

Revision of the TS SG Tube Inspection Report Contents The TS have included a requirement to report the results of SG tube inspections since at least the mid-1970's. The content of those reports has evolved with the understanding of the underlying mechanisms related to SG tube degradation.

The proposed change rearranges the existing reporting requirements for clarity. These changes are administrative.

Using industry guidelines, all licensees perform a forward-looking projection of SG tube performance until the next inspection. These assessments have been proven successful in predicting SG tube performance for more than 20 years. Licensees perform more frequent inspections should the forward-looking evaluation determine that a SG inspection is needed prior to the TS mandated interval. The proposed change requires licensees to summarize the forward-looking assessment including the methodology, inputs, and results. This information will assist the NRC in reviewing the plant's planned SG inspection program.

Paragraph "a" of the SG program requires the performance of condition monitoring assessments.

Condition monitoring assessments evaluate the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The TS requires a condition monitoring assessment to conducted whenever the SG tubes are inspected to confirm that the performance criteria are being met. The proposed change expands the current reporting requirement of the results of the conditioning monitoring assessment to include the margin to the tube integrity performance criteria and comparisons to the predicted margin. The proposed change also removes the explicit requirement to report the results of any tube pulls or in-situ testing. This type of testing is rarely performed, but if it should be performed it would be reported as part of the condition monitoring assessment summary. The additional information will assist the NRC in reviewing the licensee's condition monitoring program.

The proposed change provides an exception to reporting tube wear indications (location, orientation (if linear), measured size (if available), and voltage response) at support structures that are less than 20 percent through-wall. However, the total number of such indications is required to be reported. The reduces the amount of data to be reported while not having a significant effect on the ability of the NRC to review the inspection results.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 17 The proposed change requires reporting the results of any secondary side inspections. The SG Program does not require SG secondary side inspections. However, licensees often perform such inspections and have been informally reporting the results to the NRC. The proposed change formalizes this reporting, but the use of the term "any" clarifies that the report is not imposing new inspection requirements. Secondary side inspections are not required by the TS, but if a licensee chooses to perform them, the results should be reported.

3.3.

Editorial Improvements Various editorial improvements are made for consistency within the proposed requirements and with the STS, such as consistent use of acronyms. These improvements have no effect on the application of the requirements and are, therefore, acceptable.

4.

REGULATORY EVALUATION Section IV, "The Commission Policy," of the "Final Policy Statement on Technical Specifications Improvements for Nuclear Power Reactors" (58 Federal Register 39132), dated July 22, 1993, states in part:

The purpose of Technical Specifications is to impose those conditions or limitations upon reactor operation necessary to obviate the possibility of an abnormal situation or event giving rise to an immediate threat to the public health and safety by identifying those features that are of controlling importance to safety and establishing on them certain conditions of operation which cannot be changed without prior Commission approval.

[T]he Commission will also entertain requests to adopt portions of the improved STS, even if the licensee does not adopt all STS improvements.

The Commission encourages all licensees who submit Technical Specification related submittals based on this Policy Statement to emphasize human factors principles.

In accordance with this Policy Statement, improved STS have been developed and will be maintained for [PWR designs]. The Commission encourages licensees to use the improved STS as the basis for plant-specific Technical Specifications.

[I]t is the Commission intent that the wording and Bases of the improved STS be used to the extent practicable.

As described in the Commissions "Final Policy Statement on Technical Specifications Improvements for Nuclear Power Reactors," recommendations were made by NRC and industry task groups for new STS that include greater emphasis on human factors principles in order to add clarity and understanding to the text of the STS, and provide improvements to the Bases of STS, which provides the purpose for each requirement in the specification. Improved vendor-specific STS were developed and issued by the NRC in September 1992.

The regulation at Title 10 of the Code of Federal Regulations (10 CFR) Section 50.36(a)(1) requires an applicant for an operating license to include in the application proposed TS in accordance with the requirements of 10 CFR 50.36. The applicant must include in the Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 18 application a "summary statement of the bases or reasons for such specifications, other than those covering administrative controls." However, per 10 CFR 50.36(a)(1), these technical specification bases "shall not become part of the technical specifications." The Final Policy Statement provides the following description of the scope and the purpose of the Technical Specification Bases:

Appropriate Surveillance Requirements and Actions should be retained for each LCO

[limiting condition for operation] which remains or is included in the Technical Specifications. Each LCO, Action, and Surveillance Requirement should have supporting Bases. The Bases should at a minimum address the following questions and cite references to appropriate licensing documentation (e.g., FSAR, Topical Report) to support the Bases.

1.

What is the justification for the Technical Specification, i.e., which Policy Statement criterion requires it to be in the Technical Specifications?

2.

What are the Bases for each LCO, i.e., why was it determined to be the lowest functional capability or performance level for the system or component in question necessary for safe operation of the facility and, what are the reasons for the Applicability of the LCO?

3.

What are the Bases for each Action, i.e., why should this remedial action be taken if the associated LCO cannot be met; how does this Action relate to other Actions associated with the LCO; and what justifies continued operation of the system or component at the reduced state from the state specified in the LCO for the allowed time period?

4.

What are the Bases for each Safety Limit?

5.

What are the Bases for each Surveillance Requirement and Surveillance Frequency; i.e., what specific functional requirement is the surveillance designed to verify? Why is this surveillance necessary at the specified frequency to assure that the system or component function is maintained, that facility operation will be within the Safety Limits, and that the LCO will be met?

Note: In answering these questions the Bases for each number (e.g., Allowable Value, Response Time, Completion Time, Surveillance Frequency), state, condition, and definition (e.g., operability) should be clearly specified. As an example, a number might be based on engineering judgment, past experience, or PSA [probabilistic safety assessment] insights; but this should be clearly stated.

Additionally, 10 CFR 50.36(b) requires:

Each license authorizing operation of a utilization facility will include technical specifications. The technical specifications will be derived from the analyses and evaluation included in the safety analysis report, and amendments thereto, submitted pursuant to [10 CFR] 50.34 ["Contents of applications; technical information"]. The Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 19 Commission may include such additional technical specifications as the Commission finds appropriate.

The categories of items required to be in the TS are provided in 10 CFR 50.36(c). As required by 10 CFR 50.36(c)(2)(i), the TS will include LCOs, which are the lowest functional capability or performance levels of equipment required for safe operation of the facility. Per 10 CFR 50.36(c)(2)(i), when an LCO of a nuclear reactor is not met, the licensee shall shut down the reactor or follow any remedial action permitted by the TS until the condition can be met.

The regulation at 10 CFR 50.36(c)(3) requires TS to include items in the category of SRs, which are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the LCOs will be met.

Per 10 CFR 50.90, whenever a holder of a license desires to amend the license, application for an amendment must be filed with the Commission, fully describing the changes desired, and following as far as applicable, the form prescribed for original applications.

Per 10 CFR 50.92(a), in determining whether an amendment to a license will be issued to the applicant, the Commission will be guided by the considerations which govern the issuance of initial licenses to the extent applicable and appropriate.

The NRC staffs guidance for the review of TS is in Chapter 16, "Technical Specifications," of NUREG-0800, Revision 3, "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants" (SRP), dated March 2010 (ADAMS Accession No. ML100351425). As described therein, as part of the regulatory standardization effort, the NRC staff has prepared STS for each of the light-water reactor nuclear designs.

In conclusion, based on the considerations discussed above, the proposed revision does not alter the current manner of operation and (1) there is reasonable assurance that the health and safety of the public will not be endangered by continued operation in the proposed manner, (2) such activities will be conducted in compliance with the Commissions regulations, and (3) the approval of the proposed change will not be inimical to the common defense and security or to the health and safety of the public.

5.

REFERENCES

1. TSTF-449, Revision 4, "Steam Generator Tube Integrity," April 14, 2005. ADAMS Accession No. ML051090200.

2. "Notice of Availability of Model Application Concerning Technical Specification; Improvement to Modify Requirements Regarding Steam Generator Tube Integrity; Using the Consolidated Line Item Improvement Process," Federal Register Vol. 70, No. 87, Pg. 24126.

3. TSTF-510, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection," March 1, 2011, ADAMS Accession No. ML110610350.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 20

4. "Models for Plant-Specific Adoption of Technical Specifications Task Force Traveler TSTF-510, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection'," Federal Register Vol. 76, No. 288, Pg. 66763.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Model Application Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 1

[DATE]

10 CFR 50.90 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001 DOCKET NO. 50-[xxx]

PLANT NAME

SUBJECT:

Application to Revise Technical Specifications to Adopt TSTF-577, "Revised Frequencies for Steam Generator Tube Inspections" Pursuant to 10 CFR 50.90, [LICENSEE] is submitting a request for an amendment to the Technical Specifications (TS) for [PLANT NAME, UNIT NOS.].

[LICENSEE] requests adoption of TSTF 577, "Revised Frequencies for Steam Generator Tube Inspections." The Technical Specifications (TS) related to steam generator tube inspections and reporting are revised based on operating history.

The enclosure provides a description and assessment of the proposed changes. Attachment 1 provides the existing TS pages marked to show the proposed changes. Attachment 2 provides revised (clean) TS pages. The TS Bases are not affected by the proposed changes.

[LICENSEE] requests that the amendment be reviewed under the Consolidated Line Item Improvement Process (CLIIP). [The amendment is needed to support steam generator tube inspection activities during a refueling outage scheduled to begin [DATE]. Approval of the proposed amendment is requested within [6] months. Once approved, the amendment shall be implemented within [ ] days.

There are no regulatory commitments made in this submittal.

In accordance with 10 CFR 50.91, a copy of this application, with attachments, is being provided to the designated [STATE] Official.

[In accordance with 10 CFR 50.30(b), a license amendment request must be executed in a signed original under oath or affirmation. This can be accomplished by attaching a notarized affidavit confirming the signature authority of the signatory, or by including the following statement in the cover letter: "I declare under penalty of perjury that the foregoing is true and correct.

Executed on (date)." The alternative statement is pursuant to 28 USC 1746. It does not require notarization.]

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 2 If you should have any questions regarding this submittal, please contact [NAME, TELEPHONE NUMBER].

Sincerely,

[Name, Title]

Enclosure:

Description and Assessment Attachments: 1.

Proposed Technical Specification Changes (Mark-Up)

2.

Revised Technical Specification Pages

[The attachments are to be provided by the licensee and are not included in the model application.]

cc:

NRC Project Manager NRC Regional Office NRC Resident Inspector State Contact Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 3 ENCLOSURE DESCRIPTION AND ASSESSMENT

1.0 DESCRIPTION

[LICENSEE] requests adoption of TSTF-577, "Revised Frequencies for Steam Generator Tube Inspections." The Technical Specifications (TS) related to steam generator tube inspections and reporting are revised based on operating history.

2.0 ASSESSMENT

2.1 Applicability of Safety Evaluation

[LICENSEE] has reviewed the safety evaluation for TSTF-577 provided to the Technical Specifications Task Force in a letter dated [DATE]. This review included a review of the NRC staffs evaluation, as well as the information provided in TSTF-577. [As described herein,]

[LICENSEE] has concluded that the justifications presented in TSTF-577 and the safety evaluation prepared by the NRC staff are applicable to [PLANT, UNIT NOS.] and justify this amendment for the incorporation of the changes to the [PLANT] TS.

The current steam generator TS requirements are based on [TSTF-449, "Steam Generator Tube Integrity."][TSTF-510, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection."]

2.2 Variations

[LICENSEE is not proposing any variations from the TS changes described in TSTF-577 or the applicable parts of the NRC staffs safety evaluation dated [DATE].] [LICENSEE is proposing the following variations from the TS changes described in TSTF-577 or the applicable parts of the NRC staffs safety evaluation: describe the variations]

[The [PLANT] TS utilize different [numbering][and][titles] than the Standard Technical Specifications on which TSTF-577 was based. Specifically, [describe differences between the plant-specific TS numbering and/or titles and the TSTF-577 numbering and titles.] These differences are administrative and do not affect the applicability of TSTF-577 to the [PLANT]

TS.]

[The [PLANT] TS contain requirements that differ from the Standard Technical Specifications on which TSTF-577 was based but are encompassed in the TSTF-577 justification. [Describe differences and why TSTF-577 is still applicable.))

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 4

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Analysis

[LICENSEE] requests adoption of TSTF 577, "Performance Based Frequencies for Steam Generator Tube Inspections." The Technical Specifications (TS) related to steam generator tube inspections and reporting are revised based on operating history.

[LICENSEE] has evaluated if a significant hazards consideration is involved with the proposed amendment(s) by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:

1.

Does the proposed amendment involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No The proposed change revises the inspection frequencies for steam generator tube inspections and associated reporting requirements. Inspection frequencies are not an initiator to a steam generator tube rupture accident, or any other accident previously evaluated. As a result, the probability of any accident previously evaluated is not significantly increased. The steam generator tubes inspected by the Steam Generator Program continued to be required to meet the Steam Generator Program performance criteria and to be capable of performing any functions assumed in the accident analysis.

As a result, the consequences of any accident previously evaluated are not significantly increased.

Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2.

Does the proposed amendment create the possibility of a new or different kind of accident from any accident previously evaluated?

Response: No The proposed change revises the inspection frequencies for steam generator tube inspections and associated reporting requirements. The proposed change does not alter the design function or operation of the steam generators or the ability of a steam generator to perform the design function. The steam generator tubes continue to be required to meet the Steam Generator Program performance criteria. The proposed change does not create the possibility of a new or different kind of accident due to credible new failure mechanisms, malfunctions, or accident initiators that not considered in the design and licensing bases.

Therefore, the proposed change does not create the possibility of a new or different kind of accident from any accident previously evaluated.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Page 5

3.

Does the proposed amendment involve a significant reduction in a margin of safety?

Response: No The proposed change revises the inspection frequencies for steam generator tube inspections and associated reporting requirements. The proposed change does not change any of the controlling values of parameters used to avoid exceeding regulatory or licensing limits. The proposed change does not affect a design basis or safety limit, or any controlling value for a parameter established in the UFSAR or the license.

Therefore, the proposed change does not involve a significant reduction in a margin of safety.

Based on the above, [LICENSEE] concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of "no significant hazards consideration" is justified.

3.2 Conclusion In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commissions regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

4.0 ENVIRONMENTAL EVALUATION A review has determined that the proposed amendment would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or a significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure.

Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment.

Draft for Presubmittal Review

TSTF-577, Rev. 0 Changes to Revision 4 of the Standard Technical Specifications and Technical Specifications Based on TSTF-449 Draft for Presubmittal Review

Programs and Manuals 5.5 Babcock & Wilcox STS 5.5-6 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program An Steam Generator SG Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, tThe SG Steam Generator Program shall include the following provisions:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging [or repair] of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, [or repaired] to confirm that the performance criteria are being met.

b.

Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1.

Structural integrity performance criterion: All in-service SGsteam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), and all anticipated transients included in the design specification,) and design basis accidents.

This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials.

Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed [1 gpm] per SG [, except for specific types of degradation at specific locations as described in paragraph c of the SG Steam Generator Program].

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Babcock & Wilcox STS 5.5-7 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c.

Provisions for SG tube plugging [or repair] criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding

[40%] of the nominal tube wall thickness shall be plugged [or repaired].

REVIEWER'S NOTE----------------------------------------

Alternate tube plugging [or repair] criteria currently permitted by plant technical specifications are listed here. The description of these alternate tube plugging

[or repair] criteria should be equivalent to the descriptions in current technical specifications and should also include any allowed accident induced leakage rates for specific types of degradation at specific locations associated with tube plugging [or repair] criteria.

[The following alternate tube plugging [or repair] criteria may be applied as an alternative to the 40% depth based criteria:

1.

...]

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging [or repair] criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

REVIEWER'S NOTE-------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing. The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Babcock & Wilcox STS 5.5-8 Rev. 4.0

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG replacementinstallation.

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Babcock & Wilcox STS 5.5-9 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

[2.

After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 24 effective full power months, which defines the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]Inspect 100% of the tubes at sequential periods of 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.]

[2.

After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 72 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.] Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.]

[2.

After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 96 effective full power months, which defines the inspection period. In addition, the minimum number Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Babcock & Wilcox STS 5.5-10 Rev. 4.0 of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.]

3.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall be at the next not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

[f.

Provisions for SG tube repair methods. Steam generatorSG tube repair methods shall provide the means to reestablish the RCS pressure boundary integrity of SG tubes without removing the tube from service. For the purposes of these Specifications, tube plugging is not a repair. All acceptable tube repair methods are listed below.

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Babcock & Wilcox STS 5.5-11 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

REVIEWER'S NOTE----------------------------------------

Tube repair methods currently permitted by plant technical specifications are to be listed here. The description of these tube repair methods should be equivalent to the descriptions in current technical specifications. If there are no approved tube repair methods, this section should not be used.

1.

...]

5.5.10 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a.

Identification of a sampling schedule for the critical variables and control points for these variables,

b.

Identification of the procedures used to measure the values of the critical variables,

c.

Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage,

d.

Procedures for the recording and management of data,

e.

Procedures defining corrective actions for all off control point chemistry conditions, and

f.

A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

5.5.11 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in [Regulatory Guide], and in accordance with [Regulatory Guide 1.52, Revision 2, ASME N510-1989, and AG-1].

a.

Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < [0.05]% when tested in accordance with [Regulatory Guide 1.52, Revision 2, and ASME N510-1989] at the system flowrate specified below

[+/- 10%].

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Babcock & Wilcox STS 5.6-4 Rev. 4.0 5.6 Reporting Requirements 5.6.4 RCS PRESSURE AND TEMPERATURE LIMITS REPORT (continued)

7.

Licensees who have removed two or more capsules should compare for each surveillance material the measured increase in reference temperature (RTNDT) to the predicted increase in RTNDT; where the predicted increase in RTNDT is based on the mean shift in RTNDT plus the two standard deviation value (2) specified in Regulatory Guide 1.99, Revision 2. If the measured value exceeds the predicted value (increase in RTNDT + 2), the licensee should provide a supplement to the PTLR to demonstrate how the results affect the approved methodology.

5.6.5 Post Accident Monitoring Report When a report is required by Condition B or F of LCO 3.3.[17], "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.6

[ Tendon Surveillance Report Any abnormal degradation of the containment structure detected during the tests required by the Pre-stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken. ]

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, "Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;,

b.

Nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

Nondestructive examination techniques utilized;

2.

The location, orientation (if linear), measured size (if available), and voltage response for each indication. For tube wear at support Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Babcock & Wilcox STS 5.6-5 Rev. 4.0 structures that is less than 20 percent through-wall, only the total number of indications needs to be reported;

3.

The results of condition monitoring, including the margin to the tube integrity performance criteria and comparisons to the predicted margin;

4.

Number of tubes plugged [or repaired] during the inspection outage; and

[5. Repair method utilized and the number of tubes repaired by each repair method.]

d.

A summary of a forward-looking assessment including the methodology, inputs, and results;

b.

Active degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications, Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Babcock & Wilcox STS 5.6-6 Rev. 4.0 5.6 Reporting Requirements 5.6.7 Steam Generator Tube Inspection Report (continued)

e.

Number of tubes plugged [or repaired] during the inspection outage for each active degradation mechanism, ef.

The number and percentage of tubes plugged [or repaired] to date, and the effective plugging percentage in each SG;Total number and percentage of tubes plugged [or repaired] to date,

f.

The results of any SG secondary side inspections; and

[g.

Insert any plant-specific reporting requirements, if applicable.]

g.

The results of condition monitoring, including the results of tube pulls and in-situ testing,

[h.

The effective plugging percentage for all plugging [and tube repairs] in each SG, and]

[i.

Repair method utilized and the number of tubes repaired by each repair method.]

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Westinghouse STS 5.5-6 Rev. 4.0 5.5 Programs and Manuals 5.5.8 Inservice Testing Program (continued)

d.

Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

5.5.9 Steam Generator (SG) Program An SG Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, tThe SG Steam Generator Program shall include the following provisions:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the as found condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging [or repair] of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, [or repaired] to confirm that the performance criteria are being met.

b.

Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1.

Structural integrity performance criterion: All in-service SG steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), and all anticipated transients included in the design specification), and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Westinghouse STS 5.5-7 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued) exceed [1 gpm] per SG [, except for specific types of degradation at specific locations as described in paragraph c of the Steam GeneratorSG Program.]

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c.

Provisions for SG tube plugging [or repair] criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding

[40%] of the nominal tube wall thickness shall be plugged [or repaired].

REVIEWER'S NOTE----------------------------------------

Alternate tube plugging [or repair] criteria currently permitted by plant technical specifications are listed here. The description of these alternate tube plugging [or repair] criteria should be equivalent to the descriptions in current technical specifications and should also include any allowed accident induced leakage rates for specific types of degradation at specific locations associated with tube plugging

[or repair] criteria.

[The following alternate tube plugging [or repair] criteria may be applied as an alternative to the 40% depth based criteria:

1.

...]

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging [or repair] criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Westinghouse STS 5.5-8 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

REVIEWER'S NOTE----------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing. The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG replacementinstallation.

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 24 effective full power months, which defines the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.] Inspect 100% of the tubes at sequential periods of 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.]

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 72 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Westinghouse STS 5.5-9 Rev. 4.0 months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.]

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 96 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50%

of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.]

3.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall be at the next not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Westinghouse STS 5.5-10 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

[f.

Provisions for SG tube repair methods. Steam generatorSG tube repair methods shall provide the means to reestablish the RCS pressure boundary integrity of SG tubes without removing the tube from service. For the purposes of these Specifications, tube plugging is not a repair. All acceptable tube repair methods are listed below.

REVIEWER'S NOTE----------------------------------------

Tube repair methods currently permitted by plant technical specifications are to be listed here. The description of these tube repair methods should be equivalent to the descriptions in current technical specifications. If there are no approved tube repair methods, this section should not be used.

1.

...]

5.5.10 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a.

Identification of a sampling schedule for the critical variables and control points for these variables,

b.

Identification of the procedures used to measure the values of the critical variables,

c.

Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage,

d.

Procedures for the recording and management of data,

e.

Procedures defining corrective actions for all off control point chemistry conditions, and

f.

A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Westinghouse STS 5.6-4 Rev. 4.0 5.6 Reporting Requirements 5.6.4 RCS PRESSURE AND TEMPERATURE LIMITS REPORT (continued)

7.

The minimum temperature requirements of Appendix G to 10 CFR Part 50 shall be incorporated into the pressure and temperature limit curves.

8.

Licensees who have removed two or more capsules should compare for each surveillance material the measured increase in reference temperature (RTNDT) to the predicted increase in RTNDT; where the predicted increase in RTNDT is based on the mean shift in RTNDT plus the two standard deviation value (2) specified in Regulatory Guide 1.99, Revision 2. If the measured value exceeds the predicted value (increase RTNDT + 2), the licensee should provide a supplement to the PTLR to demonstrate how the results affect the approved methodology.

5.6.5 Post Accident Monitoring Report When a report is required by Condition B or F of LCO 3.3.[3], "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.6

[ Tendon Surveillance Report Any abnormal degradation of the containment structure detected during the tests required by the Pre-stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken. ]

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, "Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;,

b.

Nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

Nondestructive examination techniques utilized; Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Westinghouse STS 5.6-5 Rev. 4.0

2.

The location, orientation (if linear), measured size (if available), and voltage response for each indication. For tube wear at support structures that is less than 20 percent through-wall, only the total number of indications needs to be reported;

3.

The results of condition monitoring, including the margin to the tube integrity performance criteria and comparisons to the predicted margin;

4.

Number of tubes plugged [or repaired] during the inspection outage; and

[5. Repair method utilized and the number of tubes repaired by each repair method.]

d.

A summary of a forward-looking assessment including the methodology, inputs, and results;

b.

Active degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism, Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Westinghouse STS 5.6-6 Rev. 4.0 5.6 Reporting Requirements 5.6.7 Steam Generator Tube Inspection Report (continued)

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e.

Number of tubes plugged [or repaired] during the inspection outage for each active degradation mechanism, ef.

The number and percentage of tubes plugged [or repaired] to date, and the effective plugging percentage in each SG;Total number and percentage of tubes plugged [or repaired] to date,

f.

The results of any SG secondary side inspections; and

[g.

Insert any plant-specific reporting requirements, if applicable.]

g.

The results of condition monitoring, including the results of tube pulls and in-situ testing,

[h.

The effective plugging percentage for all plugging [and tube repairs] in each SG, and]

[i.

Repair method utilized and the number of tubes repaired by each repair method.]

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Combustion Engineering STS 5.5-5 Rev. 4.0 5.5 Programs and Manuals 5.5.7 Reactor Coolant Pump Flywheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel per the recommendation of Regulatory position c.4.b of Regulatory Guide 1.14, Revision 1, August 1975.

5.5.8 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components. The program shall include the following:

a.

Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

ASME OM Code and applicable Addenda terminology for inservice testing activities Required Frequencies for performing inservice testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b.

The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities,

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities, and

d.

Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

5.5.9 Steam Generator (SG) Program An Steam GeneratorSG Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, tThe SG Steam Generator Program shall include the following provisions:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Combustion Engineering STS 5.5-6 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued) induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging [or repair] of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, [or repaired] to confirm that the performance criteria are being met.

b.

Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1.

Structural integrity performance criterion: All in-service SG steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), and all anticipated transients included in the design specification,) and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed [1 gpm] per SG [, except for specific types of degradation at specific locations as described in paragraph c of the SG Steam Generator Program.]

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c.

Provisions for SG tube plugging [or repair] criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding

[40%] of the nominal tube wall thickness shall be plugged [or repaired].

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Combustion Engineering STS 5.5-7 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

REVIEWER'S NOTE----------------------------------------

Alternate tube plugging [or repair] criteria currently permitted by plant technical specifications are listed here. The description of these alternate tube plugging [or repair] criteria should be equivalent to the descriptions in current technical specifications and should also include any allowed accident induced leakage rates for specific types of degradation at specific locations associated with tube plugging

[or repair] criteria.

[The following alternate tube plugging [or repair] criteria may be applied as an alternative to the 40% depth based criteria:

1.

...]

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging [or repair] criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

REVIEWER'S NOTE----------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing. The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG replacementinstallation.

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 24 effective full power months, which defines the inspection period. Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Combustion Engineering STS 5.5-8 Rev. 4.0 begins at the conclusion of the included SG inspection outage.]Inspect 100% of the tubes at sequential periods of 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. No SG shall operate for more than 24 effective full power months or one refueling outage (whichever is less) without being inspected.]

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Combustion Engineering STS 5.5-9 Rev. 4.0 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 72 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.]

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 96 effective full power months, which defines the inspection period. In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 Combustion Engineering STS 5.5-10 Rev. 4.0 period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

Each inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50%

of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.]

3.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall be at the next not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

[f.

Provisions for SG tube repair methods. SG Steam generator tube repair methods shall provide the means to reestablish the RCS pressure boundary integrity of SG tubes without removing the tube from service. For the purposes of these Specifications, tube plugging is not a repair. All acceptable tube repair methods are listed below.

REVIEWER'S NOTE----------------------------------------

Tube repair methods currently permitted by plant technical specifications are to be listed here. The description of these tube repair methods should be equivalent to the descriptions in current technical specifications. If there are no approved tube repair methods, this section should not be used.

1.

...]

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Combustion Engineering STS 5.6-4 Rev. 4.0 5.6 Reporting Requirements 5.6.4 RCS Pressure and Temperature Limits Report (continued)

7.

Licensees who have removed two or more capsules should compare for each surveillance material the measured increase in reference temperature (RTNDT) to the predicted increase in RTNDT; where the predicted increase in RTNDT is based on the mean shift in RTNDT plus the two standard deviation value (2) specified in Regulatory Guide 1.99, Revision 2. If the measured value exceeds the predicted value (increase in RTNDT + 2), the licensee should provide a supplement to the PTLR to demonstrate how the results affect the approved methodology.

5.6.5 Post Accident Monitoring Report When a report is required by Condition B or F of LCO 3.3.[11], "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.6 Tendon Surveillance Report

[ Any abnormal degradation of the containment structure detected during the tests required by the Pre-stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken. ]

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, "Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;,

b.

Nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

Nondestructive examination techniques utilized;

2.

The location, orientation (if linear), measured size (if available), and voltage response for each indication. For tube wear at support structures that is less than 20 percent through-wall, only the total number of indications needs to be reported; Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Combustion Engineering STS 5.6-5 Rev. 4.0

3.

The results of condition monitoring, including the margin to the tube integrity performance criteria and comparisons to the predicted margin;

4.

Number of tubes plugged [or repaired] during the inspection outage; and

[5. Repair method utilized and the number of tubes repaired by each repair method.]

d.

A summary of a forward-looking assessment including the methodology, inputs, and results;

b.

Active degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications, Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 Combustion Engineering STS 5.6-6 Rev. 4.0 5.6 Reporting Requirements 5.6.7 Steam Generator Tube Inspection Report (continued)

e.

Number of tubes plugged [or repaired] during the inspection outage for each active degradation mechanism, ef.

The number and percentage of tubes plugged [or repaired] to date, and the effective plugging percentage in each SG;Total number and percentage of tubes plugged [or repaired] to date,

f.

The results of any SG secondary side inspections; and

[g.

Insert any plant-specific reporting requirements, if applicable.]

g.

The results of condition monitoring, including the results of tube pulls and in-situ testing,

[h.

The effective plugging percentage for all plugging [and tube repairs] in each SG, and]

[i.

Repair method utilized and the number of tubes repaired by each repair method.]

Markup Based on STS Revision 4 and TSTF-449 TSTF-577, Rev. 0 Draft for Presubmittal Review

TSTF-577, Rev. 0 Changes to Technical Specifications Based on TSTF-510 Draft for Presubmittal Review

Programs and Manuals 5.5 BWOG STS 5.5-5 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.8 Inservice Testing Program (continued)

ASME OM Code and applicable Addenda terminology for inservice testing activities Required Frequencies for performing inservice testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b.

The provisions of SR 3.0.2 are applicable to the above required Frequencies and other normal and accelerated Frequencies specified in the Inservice Testing Program for performing inservice testing activities,

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities, and

d.

Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

5.5.9 Steam Generator (SG) Program An Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, tThe SG Steam Generator Program shall include the following:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging [or repair] of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, [or repaired] to confirm that the performance criteria are being met.

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 BWOG STS 5.5-6 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

b.

Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1.

Structural integrity performance criterion: All in-service SG steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), all anticipated transients included in the design specification, and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed [1 gpm] per SG [, except for specific types of degradation at specific locations as described in paragraph c of the SG Steam Generator Program].

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c.

Provisions for SG tube plugging [or repair] criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding

[40%] of the nominal tube wall thickness shall be plugged [or repaired].

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 BWOG STS 5.5-7 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

REVIEWER'S NOTE----------------------------------------

Alternate tube plugging [or repair] criteria currently permitted by plant technical specifications are listed here. The description of these alternate tube plugging

[or repair] criteria should be equivalent to the descriptions in current technical specifications and should also include any allowed accident induced leakage rates for specific types of degradation at specific locations associated with tube plugging [or repair] criteria.

[The following alternate tube plugging [or repair] criteria may be applied as an alternative to the 40% depth based criteria:

1.

...]

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging [or repair] criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

REVIEWER'S NOTE-------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing. The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

[2.

After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG steam generator at least every 24 effective full power months, which defines the inspection period. or at least every refueling outage (whichever results in more frequent inspections). In addition, inspect 100% of the tubes at sequential Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 BWOG STS 5.5-8 Rev. 3.1, 12/01/05 periods of 60 effective full power months beginning after the first refueling outage inspection following SG installation. Each 60 effective full power month inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube repair criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 BWOG STS 5.5-9 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

[2.

After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 7248 effective full power months, which defines the inspection period. or at least every other refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, and c below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

Reviewer's Note ------------------------------------

A licensee may elect to retain historical and existing inspection period lengths in order to not revise those inspection periods.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 120 effective full power months. This constitutes the first inspection period; b)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; and c)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods.

[2.

After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 9672 effective full power months, which defines the inspection period. or at least every third Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 BWOG STS 5.5-10 Rev. 3.1, 12/01/05 refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair] criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

Reviewer's Note ------------------------------------

A licensee may elect to retain historical and existing inspection period lengths in order to not revise those inspection periods.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b)

During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

3.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall be at the next not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 BWOG STS 5.5-11 Rev. 3.1, 12/01/05 crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

[f.

Provisions for SG tube repair methods. SG Steam generator tube repair methods shall provide the means to reestablish the RCS pressure boundary integrity of SG tubes without removing the tube from service. For the purposes of these Specifications, tube plugging is not a repair. All acceptable tube repair methods are listed below.

REVIEWER'S NOTE----------------------------------------

Tube repair methods currently permitted by plant technical specifications are to be listed here. The description of these tube repair methods should be equivalent to the descriptions in current technical specifications. If there are no approved tube repair methods, this section should not be used.

1.

...]

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 BWOG STS 5.6-4 Rev. 3.1, 12/01/05 5.6 Reporting Requirements 5.6.5 Post Accident Monitoring Report When a report is required by Condition B or F of LCO 3.3.[17], "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.6

[ Tendon Surveillance Report Any abnormal degradation of the containment structure detected during the tests required by the Pre-stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken. ]

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, "Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;,

b.

Nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

Nondestructive examination techniques utilized;

2.

The location, orientation (if linear), measured size (if available), and voltage response for each indication. For tube wear at support structures that is less than 20 percent through-wall, only the total number of indications needs to be reported;

3.

The results of condition monitoring, including the margin to the tube integrity performance criteria and comparisons to the predicted margin;

4.

Number of tubes plugged [or repaired] during the inspection outage; and

[5. Repair method utilized and the number of tubes repaired by each repair method.]

d.

A summary of a forward-looking assessment including the methodology, inputs, and results; Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 BWOG STS 5.6-5 Rev. 3.1, 12/01/05

b.

Degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e.

Number of tubes plugged [or repaired] during the inspection outage for each degradation mechanism, ef.

The number and percentage of tubes plugged [or repaired] to date, and the effective plugging percentage in each SGsteam generator;,

f.

The results of any SG secondary side inspections; and

[g.

Insert any plant-specific reporting requirements, if applicable.]

g.

The results of condition monitoring, including the results of tube pulls and in-situ testing,

[h.

Repair method utilized and the number of tubes repaired by each repair method.]

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 WOG STS 5.5-6 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program An SGSteam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, tThe SG Steam Generator Program shall include the following:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the as found condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging [or repair] of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, [or repaired] to confirm that the performance criteria are being met.

b.

Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1.

Structural integrity performance criterion: All in-service SG steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), all anticipated transients included in the design specification, and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed [1 gpm] per SG [, except for specific types of degradation at specific locations as described in paragraph c of the SG Steam Generator Program].

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 WOG STS 5.5-7 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c.

Provisions for SG tube plugging [or repair] criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding

[40%] of the nominal tube wall thickness shall be plugged [or repaired].

REVIEWER'S NOTE----------------------------------------

Alternate tube plugging [or repair] criteria currently permitted by plant technical specifications are listed here. The description of these alternate tube plugging [or repair] criteria should be equivalent to the descriptions in current technical specifications and should also include any allowed accident induced leakage rates for specific types of degradation at specific locations associated with tube plugging

[or repair] criteria.

[The following alternate tube plugging [or repair] criteria may be applied as an alternative to the 40% depth based criteria:

1.

...]

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging [or repair] criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 WOG STS 5.5-8 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

REVIEWER'S NOTE----------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing. The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG steam generator at least every 24 effective full power months, which defines the inspection period. or at least every refueling outage (whichever results in more frequent inspections). In addition, inspect 100% of the tubes at sequential periods of 60 effective full power months beginning after the first refueling outage inspection following SG installation. Each 60 effective full power month inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube repair criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 7248 effective full power months, which defines the inspection period or at least every other refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, and c below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair]

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 WOG STS 5.5-9 Rev. 3.1, 12/01/05 criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

Reviewer's Note ------------------------------------

A licensee may elect to retain historical and existing inspection period lengths in order to not revise those inspection periods.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 120 effective full power months. This constitutes the first inspection period; b)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; and c)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods.

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 9672 effective full power months, which defines the inspection period or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair]

criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 WOG STS 5.5-10 Rev. 3.1, 12/01/05 period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

Reviewer's Note ------------------------------------

A licensee may elect to retain historical and existing inspection period lengths in order to not revise those inspection periods.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b)

During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

3.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation mechanism that caused the crack indication shall be at the next not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 WOG STS 5.5-11 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

[f.

Provisions for SG tube repair methods. SG Steam generator tube repair methods shall provide the means to reestablish the RCS pressure boundary integrity of SG tubes without removing the tube from service. For the purposes of these Specifications, tube plugging is not a repair. All acceptable tube repair methods are listed below.

REVIEWER'S NOTE----------------------------------------

Tube repair methods currently permitted by plant technical specifications are to be listed here. The description of these tube repair methods should be equivalent to the descriptions in current technical specifications. If there are no approved tube repair methods, this section should not be used.

1.

...]

5.5.10 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a.

Identification of a sampling schedule for the critical variables and control points for these variables,

b.

Identification of the procedures used to measure the values of the critical variables,

c.

Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage,

d.

Procedures for the recording and management of data,

e.

Procedures defining corrective actions for all off control point chemistry conditions, and

f.

A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 WOG STS 5.6-4 Rev. 3.1, 12/01/05 5.6 Reporting Requirements 5.6.5 Post Accident Monitoring Report When a report is required by Condition B or F of LCO 3.3.[3], "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.6

[ Tendon Surveillance Report Any abnormal degradation of the containment structure detected during the tests required by the Pre-stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken. ]

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, "Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;,

b.

Nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

Nondestructive examination techniques utilized;

2.

The location, orientation (if linear), measured size (if available), and voltage response for each indication. For tube wear at support structures that is less than 20 percent through-wall, only the total number of indications needs to be reported;

3.

The results of condition monitoring, including the margin to the tube integrity performance criteria and comparisons to the predicted margin;

4.

Number of tubes plugged [or repaired] during the inspection outage; and

[5. Repair method utilized and the number of tubes repaired by each repair method.]

d.

A summary of a forward-looking assessment including the methodology, inputs, and results; Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 WOG STS 5.6-5 Rev. 3.1, 12/01/05

b.

Degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e.

Number of tubes plugged [or repaired] during the inspection outage for each degradation mechanism, ef.

The number and percentage of tubes plugged [or repaired] to date, and the effective plugging percentage in each SGsteam generator;,

f.

The results of any SG secondary side inspections; and

[g.

Insert any plant-specific reporting requirements, if applicable.]

g.

The results of condition monitoring, including the results of tube pulls and in-situ testing,

[h.

Repair method utilized and the number of tubes repaired by each repair method.]

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 CEOG STS 5.5-5 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.8 Inservice Testing Program (continued)

ASME OM Code and applicable Addenda terminology for inservice testing activities Required Frequencies for performing inservice testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b.

The provisions of SR 3.0.2 are applicable to the above required Frequencies and other normal and accelerated Frequencies specified in the Inservice Testing Program for performing inservice testing activities,

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities, and

d.

Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

5.5.9 Steam Generator (SG) Program An SGSteam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, tThe SG Steam Generator Program shall include the following:

a.

Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging [or repair] of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected, plugged, [or repaired] to confirm that the performance criteria are being met.

b.

Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 CEOG STS 5.5-6 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

1.

Structural integrity performance criterion: All in-service SG steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down), all anticipated transients included in the design specification, and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2.

Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed [1 gpm] per SG [, except for specific types of degradation at specific locations as described in paragraph c of the SG Steam Generator Program.]

3.

The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c.

Provisions for SG tube plugging [or repair] criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding

[40%] of the nominal tube wall thickness shall be plugged [or repaired].

REVIEWER'S NOTE----------------------------------------

Alternate tube plugging [or repair] criteria currently permitted by plant technical specifications are listed here. The description of these alternate tube plugging [or repair] criteria should be equivalent to the descriptions in current technical specifications and should also include any allowed accident induced leakage rates for specific types of degradation at specific locations associated with tube plugging

[or repair] criteria.

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 CEOG STS 5.5-7 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

[The following alternate tube plugging [or repair] criteria may be applied as an alternative to the 40% depth based criteria:

1.

...]

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube plugging [or repair] criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. A degradation assessment shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

REVIEWER'S NOTE----------------------------------------

Plants are to include the appropriate Frequency (e.g., select the appropriate Item 2.) for their SG design. The first Item 2 is applicable to SGs with Alloy 600 mill annealed tubing. The second Item 2 is applicable to SGs with Alloy 600 thermally treated tubing. The third Item 2 is applicable to SGs with Alloy 690 thermally treated tubing.

1.

Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG steam generator at least every 24 effective full power months, which defines the inspection period. or at least every refueling outage (whichever results in more frequent inspections). In addition, inspect 100% of the tubes at sequential periods of 60 effective full power months beginning after the first refueling outage inspection following SG installation. Each 60 effective full power month inspection period may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube repair criteria, the Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 CEOG STS 5.5-8 Rev. 3.1, 12/01/05 minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period.

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 7248 effective full power months, which defines the inspection period. or at least every other refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, and c below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair]

criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

Reviewer's Note ------------------------------------

A licensee may elect to retain historical and existing inspection period lengths in order to not revise those inspection periods.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 120 effective full power months. This constitutes the first inspection period; b)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; and c)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods.

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 CEOG STS 5.5-9 Rev. 3.1, 12/01/05 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

[2. After the first refueling outage following SG installation, inspect 100%

of the tubes in each SG at least every 9672 effective full power months, which defines the inspection period. or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging [or repair]

criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.]

Reviewer's Note ------------------------------------

A licensee may elect to retain historical and existing inspection period lengths in order to not revise those inspection periods.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b)

During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c)

During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d)

During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

3.

If crack indications are found in any SG tube, then the next inspection for each affected and potentially affected SG for the degradation Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Programs and Manuals 5.5 CEOG STS 5.5-10 Rev. 3.1, 12/01/05 mechanism that caused the crack indication shall be at the next not exceed 24 effective full power months or one refueling outage (whichever results in more frequent inspections). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

[f.

Provisions for SG tube repair methods. SG Steam generator tube repair methods shall provide the means to reestablish the RCS pressure boundary integrity of SG tubes without removing the tube from service. For the purposes of these Specifications, tube plugging is not a repair. All acceptable tube repair methods are listed below.

REVIEWER'S NOTE----------------------------------------

Tube repair methods currently permitted by plant technical specifications are to be listed here. The description of these tube repair methods should be equivalent to the descriptions in current technical specifications. If there are no approved tube repair methods, this section should not be used.

1.

...]

5.5.10 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a.

Identification of a sampling schedule for the critical variables and control points for these variables, Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 CEOG STS 5.6-4 Rev. 3.1, 12/01/05 5.6 Reporting Requirements 5.6.5 Post Accident Monitoring Report When a report is required by Condition B or F of LCO 3.3.[11], "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.6 Tendon Surveillance Report

[ Any abnormal degradation of the containment structure detected during the tests required by the Pre-stressed Concrete Containment Tendon Surveillance Program shall be reported to the NRC within 30 days. The report shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective action taken. ]

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, "Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;,

b.

Nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

Nondestructive examination techniques utilized;

2.

The location, orientation (if linear), measured size (if available), and voltage response for each indication. For tube wear at support structures that is less than 20 percent through-wall, only the total number of indications needs to be reported;

3.

The results of condition monitoring, including the margin to the tube integrity performance criteria and comparisons to the predicted margin;

4.

Number of tubes plugged [or repaired] during the inspection outage; and

[5. Repair method utilized and the number of tubes repaired by each repair method.]

d.

A summary of a forward-looking assessment including the methodology, inputs, and results; Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

Reporting Requirements 5.6 CEOG STS 5.6-5 Rev. 3.1, 12/01/05

b.

Degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e.

Number of tubes plugged [or repaired] during the inspection outage for each degradation mechanism, ef.

The number and percentage of tubes plugged [or repaired] to date, and the effective plugging percentage in each SGsteam generator;,

f.

The results of any SG secondary side inspections; and

[g.

Insert any plant-specific reporting requirements, if applicable.]

g.

The results of condition monitoring, including the results of tube pulls and in-situ testing,

[h.

Repair method utilized and the number of tubes repaired by each repair method.]

Markup Based on TSTF-510 TSTF-577, Rev. 0 Draft for Presubmittal Review

ML20113E848

Text

Description:

SUMMARY

SUMMARY

SUBJECT:

Enclosure:

1.0 DESCRIPTION

2.0 ASSESSMENT

3.0 REGULATORY ANALYSIS

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