L-2024-113, License Amendment Request 294, Application to Revise Technical Specifications to Adopt TSTF- 577, Revised Frequencies for Steam Generator Tube Inspections

License Amendment Request 294, Application to Revise Technical Specifications to Adopt TSTF- 577, Revised Frequencies for Steam Generator Tube Inspections

ML24206A109
Person / Time
Site:	Point Beach
Issue date:	07/24/2024
From:	Rasmus P Point Beach
To:	Office of Nuclear Reactor Regulation, Document Control Desk
References
L-2024-113
Download: ML24206A109 (1)

Text

Attn: Document Control Desk U. S. Nuclear Regulatory Commission Washington DC 20555-0001 RE:

Point Beach Nuclear Plant, Units 1 and 2 Docket Nos. 50-266 and 50-301 Renewed Facility Operating Licenses DPR-24 and DPR-27 July 24, 2024 L-2024-113 10 CFR 50.90 License Amendment Request 294, Application to Revise Technical Specifications to Adopt TSTF-577, "Revised Frequencies for Steam Generator Tube Inspections" Pursuant to 10 CFR 50.90, NextEra Energy Point Beach, LLC (NextEra) is submitting a request for an amendment to the Technical Specifications (TS) for Point Beach Nuclear Plant Units 1 and 2 (Point Beach).

NextEra requests adoption of TSTF-577, "Revised Frequencies for Steam Generator Tube Inspections,"

which is an approved change to the Standard Technical Specifications (STS), into the Point Beach TS. The TS related to steam generator (SG) 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.

NextEra requests that the amendment be reviewed under the Consolidated Line-Item Improvement Process (CU IP). Approval of the proposed amendment is requested within 6 months of completion of the NRC's acceptance review. Once approved, the amendment shall be implemented within 60 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 of Wisconsin official.

Should you have any questions regarding this submittal, please contact Mr. Kenneth Mack, Senior Manager, Licensing and Regulatory Compliance, at 561-904-3635.

I declare under penalty of perjury that the foregoing is true and correct.

Executed on the ~

day of July 2024.

Sincerely,

./

~

Paul Rasmus General Manager, Regulatory Affairs

Enclosure:

Description and Assessment Attachments:

1.

Proposed Technical Specification Changes (Mark-Up)

2. Revised Technical Specification Pages NextEra Energy Point Beach, LLC 6610 Nuclear Road, Two Rivers, WI 54241

Point Beach Nuclear Plant, Units 1 and 2 Docket Nos. 50-266 and 50-301 cc:

USNRC Regional Administrator, Region Ill Project Manager, USNRC, Point Beach Nuclear Plant Resident Inspector, USNRC, Point Beach Nuclear Plant Mr. Mike Verhagan, Department of Commerce, State of Wisconsin L-2024-113 Page 2 of 2

Point Beach Nuclear Plant, Units 1 and 2 Docket Nos. 50-266 and 50-301

1.0 DESCRIPTION

ENCLOSURE DESCRIPTION AND ASSESSMENT L-2024-11 3 Enclosure Page 1 of 20 NextEra Energy Point Beach, LLC (NextEra) requests adoption of TSTF-577, "Revised Frequencies for Steam Generator Tube Inspections," which is an approved change to the Standard Technical Specifications (STS), into the Point Beach Nuclear Plant, Units 1 and 2, (Point Beach) Technical Specifications (TS). The TS related to steam generator (SG) tube inspections and reporting are revised based on operating history.

2.0 ASSESSMENT

2.1 Applicability of Safety Evaluation NextEra has reviewed the safety evaluation for TSTF-577 provided to the Technical Specifications Task Force in a letter dated April 14, 2021. This review included a review of the NRC staff's evaluation, as well as the information provided in TSTF-577. As described herein, NextEra has concluded that the justifications presented in TSTF-577 and the safety evaluation prepared by the NRC staff are applicable to Point Beach Units 1 and 2 and justify this amendment for the incorporation of the changes to the Point Beach TS.

The current SG TS requirements are based on TSTF-510, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection." The Unit 1 SG tubes are made from Thermally Treated Alloy 600 (Alloy 600TT) and the Unit 2 SG tubes are made from Thermally Treated Alloy 690 (Alloy 690TT).

The Unit 1 initial inspection period described in the SG Program, paragraph d.2, will begin in March 2022. The Unit 2 initial inspection period described in the SG Program, paragraph d.2, will begin in October 2021. NextEra will submit SG Tube Inspection Reports meeting the revised TS 5.6.8 requirements within 30 days after implementation of the license amendment.

2.2 Variations NextEra is proposing the following variations from the TS changes described in TSTF-577 or the applicable parts of the NRC staff's safety evaluation:

1. The Point Beach Steam Generator Program, Paragraph d, contains separate requirements for Unit 1 and Unit 2 due to the differences in the SG tube alloy. Many of these differences are eliminated by TSTF-577 which includes the exception, "except for any portions of the tube that are exempt from inspection by alternate repair criteria." In paragraph d.3 the Alloy 600TT allowance to defer an inspection after detecting cracking is only applicable to Unit 1.

2. In Point Beach Specification 5.5.8, an editorial correction is made to Paragraph d.

The last sentence, last word is revised to replace "location" to "locations" in order to be consistent with TSTF-577.

3. In Point Beach Specification 5.5.8, Paragraph b.1, an editorial correction is made to delete the word "and" in the first sentence. This change is consistent with TSTF-577.

Point Beach Nuclear Plant, Units 1 and 2 Docket Nos. 50-266 and 50-301 L-2024-113 Enclosure Page 2 of 20

4.

Point Beach Specification 5.6.8 is revised to place the title of Specification 5.5.8 in quotes. This change is consistent with TSTF-577.

These differences are administrative and do not affect the applicability of TSTF-577 to the Point Beach TS.

The Point Beach Steam Generator Program TS currently contain a provision for an alternate tube plugging criteria for Unit 1. The description of the alternate tube plugging criteria in the proposed change are equivalent to the descriptions in the current TS.

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Analysis NextEra requests adoption of TSTF-577, "Revised Frequencies for Steam Generator Tube Inspections," which is an approved change to the Standard Technical Specifications (STS), into the Point Beach Units 1 and 2 Technical Specifications (TS).

The TS related to steam generator (SG) tube inspections and reporting are revised based on operating history.

NextEra 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 SG tube inspections and associated reporting requirements. The SG inspections are conducted as part of the SG Program to ensure and demonstrate that performance criteria for tube structural integrity and accident leakage integrity are met. These performance criteria are consistent with the plant design and licensing basis.

With the proposed changes to the inspection frequencies, the SG Program must still demonstrate that the performance criteria are met. As a result, the probability of any accident previously evaluated is not significantly increased and 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 SG tube inspections and associated reporting requirements. The proposed change does not alter the design function or operation of the SGs or the ability of an SG to perform the design function. The SG tubes continue to be required to meet the SG 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,

Point Beach Nuclear Plant, Units 1 and 2 Docket Nos. 50-266 and 50-301 L-2024-113 Enclosure Page 3 of 20 malfunctions, or accident initiators that are 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.

(3)

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

Response: No The proposed change revises the inspection frequencies for SG 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, NextEra 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 Commission's 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 CONSIDERATION

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.

Point Beach Nuclear Plant, Units 1 and 2 Docket Nos. 50-266 and 50-301 ATTACHMENT 1 PROPOSED TECHNICAL SPECIFICATION PAGES (MARKUP)

(9 pages follow)

L-2024-113 Enclosure Page 4 of 20

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Risk Informed Completion Time Program (continued)

e.

The risk assessment approaches and methods shall be acceptable to the NRC. The plant PRA shall be based on the as-built, as-operated, and maintained plant; and reflect the operating experience at the plant, as specified in Regulatory Guide 1.200, Revision 2. Methods to assess the risk from extending the Completion Times must be PRA methods approved for use with this program, or other methods approved by the NRC for generic use; and any change in the PRA methods to assess risk that are outside these approval boundaries require prior NRC approval.

5.5.8 Steam Generator (SG) Program Point Beach An SG Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the 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 of tubes.

Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged 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), ami--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 5.5-7 Unit 1 - Amendment No.~

Unit 2 - Amendment No. ~

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Point Beach Steam Generator (SG) (continued) 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 500 gallons per day per SG.

3.

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

c.

Provisions for SG tube plugging 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.

The following alternate tube plugging criteria shall be applied as an alternative to the 40% depth based criteria:

For Unit 1 only, tubes with service-induced flaws located greater than 20.6 inches below the top of the tubesheet do not require plugging.

Tubes with service-induced flaws located in the portion of the tube from the top of the tubesheet to 20.6 inches below the top of the tubesheet shall be plugged upon detection.

This alternate tube plugging criteria is not applicable to the tube at row 38 column 69 in the A steam generator, which is not expanded in the hot leg the full length of the tubesheet.

This tube has been removed from service by plugging (during U1R31).

d.

Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. For Unit 1, tThe 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 except for any portions of the tube that are exempt from inspection by alternate repair criteria, from 20.6 inches below the top of 5.5-8 Unit 1 - Amendment No. 74 Unit 2 - Amendment No. 7J.

Programs and Manuals 5.5 5.5 Programs and Manuals Point Beach the tubesheet on the hot leg side to 20.6 inches below the top of the tubesheet on the cold leg side and that may satisfy the applicable tube plugging criteria. For Unit 2, the number and portions of the tubes inspected and methods of inspeotion 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 criteria. For Unit 1 and Unit 2:

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.

1.

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

2.

i. Unit 1 (alloy 600 Thermally Treated tubes): After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 5448 effective full power months, which defines the inspection period. If none of the SG tubes have ever experienced cracking other than in regions that are exempt from inspection by alternate repair criteria and the SG inspection was performed with enhanced probes, the inspection period may be extended to 72 effective full power months. Enhanced probes have a capability to detect flaws of any type equivalent to or better than array probe technology. The enhanced probes shall be used from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet except any portions of the tube that are exempt from inspection by alternate repair criteria. If there are regions where enhanced probes cannot be used, the tube inspection techniques shall be capable of detecting all forms of existing and potential degradation in that region 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 belo111. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a teohnique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the 5.5-9 Unit 1 - Amendment No. 2--7-Unit 2 - Amendment No.~

Programs and Manuals 5.5 5.5 Programs and Manuals ii.

Point Beach 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 belmv may be extended up to 3 effective full po1Ner 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.

a)

After the first refueling outage following SG installation, inspect 100% of the tubes during the next 120 effeetive full po*.a.<er months.

This eonstitutes the first inspection period; b)

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

During the remaining life of the SGs, inspeet 100% of the tubes every 72 effective full pov;er months. This constitutes the third and subsequent inspection periods.

Unit 2 (alloy 690 Thermally Treated tubes): 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 inspeetions). In addition, the minimum number of tubes inspected at eaeh scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages seheduled 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 loeation and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected 'Nith 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 5.5-10 Unit 1 - Amendment No. ~

Unit 2 - Amendment No. ~

Programs and Manuals 5.5 5.5 Programs and Manuals Point Beach ossurring at this losation divided by the total number of times the SG is ssheduled to be inspested in the inspestion period. Eash inspestion period defined below may be extended up to 3 effestive full power months to inslude a SG inspestion outage in an inspestion period and the subsequent inspestion period begins at the sonslusion of the insluded SG inspestion outage.

a) After the first refueling outage following SG installation, inspest 100% of the tubes during the next 14 4 effestive full pmver months.

This sonstitutes the first inspestion period; b)

During the next 120 effestive full po11,1er months, inspest 100% of the tubes. This sonstitutes the sesond inspestion period; s)

During the next 96 effestive full power months, inspest 100% of the tubes. This sonstitutes the third inspestion period; and d) During the remaining life of the SGs, inspest 100% of the tubes every 72 effestive full po1Ner months. This sonstitutes the fourth and subsequent inspestion periods.

3.

For Unit 1, if crack indications are found in any SG tube excluding any region that is exempt from inspection by alternate repair criteriafrem-20.6 in shes below the top of the tubesheet on the hot leg side to 20.6 inshes below the top of the tubesheet on the sold leg side, 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 exseed 24 effestive full power months or one refueling outage-(whishever results in more frequent inspestions), but may be deferred to the following refueling outage if the 100% inspection of all SGs was performed with enhanced probes as described in paragraph d.2. 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.

For Unit 2, 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 exseed 24 effestive full power months or one refueling outage-(whishever results in more frequent inspestions). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like 5.5-11 Unit 1 - Amendment No. 2--7-Unit 2 - Amendment No. ~

Programs and Manuals 5.5 5.5 Programs and Manuals Point Beach 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.

5.5-12 Unit 1 - Amendment No. 74-Unit 2 - Amendment No. ~

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 5.6.7 5.6.8 Point Beach PAM 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.

Tendon Surveillance Report Abnormal conditions observed during testing will be evaluated to determine the effect of such conditions on containment structural integrity. This evaluation should be completed within 30 days of the identification of the condition. Any condition which is determined in this evaluation to have a significant adverse effect on containment structural integrity will be considered an abnormal degradation of the containment structure.

Any abnormal degradation of the containment structure identified during the engineering evaluation of abnormal conditions shall be reported to the Nuclear Regulatory Commission pursuant to the requirements of 10 CFR 50.4 within thirty days of that determination. Other conditions that indicate possible effects on the integrity of two or more tendons shall be reportable in the same manner. Such reports shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedure and the corrective action taken.

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 5.5.8, " Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;,

b.

The nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

The nondestructive examination techniques utilized;

2.

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

and voltage response for each indication. For tube wear at 5.6-6 Unit 1 - Amendment No. ~

Unit 2 - Amendment No. ~

Reporting Requirements 5.6 5.6 Reporting Requirements Point Beach support structures less than 20 percent through-wall, only the total number of indications needs to be reported;

3.

A description of the condition monitoring assessment and results, including the margin to the tube integrity performance criteria and comparison with the margin predicted to exist at the inspection by the previous forward-looking tube integrity assessment; and

4.

The number of tubes plugged during the inspection outage.

d.

An analysis summary of the tube integrity conditions predicted to exist at the next scheduled inspection (the forward-looking tube integrity assessment) relative to the applicable performance criteria, including the analysis methodology, inputs, and results;

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, 5.6-7 Unit 1 - Amendment No. ~

Unit 2 - Amendment No.~

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.8 Point Beach Steam Generator Tube Inspection Report (continued)

e.

Number of tubes plugged during the inspection outage for each degradation mechanism, ef.

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

f.

The results of any SG secondary side inspections;

g.

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

gfl. For Unit 1 only, the primary to secondary leakage rate observed in each SG (if it is not practical to assign the leakage to an individual SG, the entire primary to secondary leakage should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report;,

hi.

For Unit 1 only, the calculated accident induced leakage rate from the portion of the tubes below 20.6 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident induced leakage rate from the most limiting accident is less than 5.22 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined;, and ij.

For Unit 1 only, the results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.

5.6-8 Unit 1 - Amendment No.~

Unit 2 - Amendment No. ~

Point Beach Nuclear Plant, Units 1 and 2 Docket Nos. 50-266 and 50-301 ATTACHMENT 2 REVISED TECHNICAL SPECIFICATION PAGES (6 pages follow)

L-2024-113 Enclosure Page 14 of 20

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Risk Informed Completion Time Program (continued)

e.

The risk assessment approaches and methods shall be acceptable to the NRC. The plant PRA shall be based on the as-built, as-operated, and maintained plant; and reflect the operating experience at the plant, as specified in Regulatory Guide 1.200, Revision 2. Methods to assess the risk from extending the Completion Times must be PRA methods approved for use with this program, or other methods approved by the NRC for generic use; and any change in the PRA methods to assess risk that are outside these approval boundaries require prior NRC approval.

5.5.8 Steam Generator (SG) Program Point Beach An SG Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the SG 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 of tubes.

Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged 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 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 5.5-7 Unit 1 - Amendment No. 74 Unit 2 - Amendment No. ~

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Point Beach Steam Generator (SG) Program (continued) 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 500 gallons per day per SG.

3.

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

c.

Provisions for SG tube plugging 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.

The following alternate tube plugging criteria shall be applied as an alternative to the 40% depth based criteria:

For Unit 1 only, tubes with service-induced flaws located greater than 20.6 inches below the top of the tubesheet do not require plugging.

Tubes with service-induced flaws located in the portion of the tube from the top of the tubesheet to 20.6 inches below the top of the tubesheet shall be plugged upon detection.

This alternate tube plugging criteria is not applicable to the tube at row 38 column 69 in the A steam generator, which is not expanded in the hot leg the full length of the tubesheet.

This tube has been removed from service by plugging (during U1 R31).

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 except for any portions of the tube that are exempt from inspection by alternate repair criteria, and that may satisfy the applicable tube plugging 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 5.5-8 Unit 1 - Amendment No. ~

Unit 2 - Amendment No.~

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Point Beach Steam Generator (SG) Program (continued) 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.

1.

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

2.

i. Unit 1 (alloy 600 Thermally Treated tubes): After the first refueling outage following SG installation, inspect 100% of the tubes in each SG at least every 54 effective full power months, which defines the inspection period. If none of the SG tubes have ever experienced cracking other than in regions that are exempt from inspection by alternate repair criteria and the SG inspection was performed with enhanced probes, the inspection period may be extended to 72 effective full power months. Enhanced probes have a capability to detect flaws of any type equivalent to or better than array probe technology. The enhanced probes shall be used from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet except any portions of the tube that are exempt from inspection by alternate repair criteria. If there are regions where enhanced probes cannot be used, the tube inspection techniques shall be capable of detecting all forms of existing and potential degradation in that region.

ii.

Unit 2 (alloy 690 Thermally Treated tubes): 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.

3.

For Unit 1, if crack indications are found in any SG tube excluding any region that is exempt from inspection by alternate repair criteria, 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, but may be deferred to the following refueling outage if the 100% inspection of all SGs was performed with enhanced probes as described in paragraph d.2. 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 5.5-9 Unit 1 - Amendment No. U-i Unit 2 - Amendment No. ~

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Point Beach Steam Generator (SG) Program (continued) associated with a crack(s), then the indication need not be treated as a crack.

For Unit 2, 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.

e.

Provisions for monitoring operational primary to secondary LEAKAGE.

5.5-10 Unit 1 - Amendment No. 2-7 Unit 2 - Amendment No. ~

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 PAM 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.

5.6.7 Tendon Surveillance Report Abnormal conditions observed during testing will be evaluated to determine the effect of such conditions on containment structural integrity. This evaluation should be completed within 30 days of the identification of the condition. Any condition which is determined in this evaluation to have a significant adverse effect on containment structural integrity will be considered an abnormal degradation of the containment structure.

Any abnormal degradation of the containment structure identified during the engineering evaluation of abnormal conditions shall be reported to the Nuclear Regulatory Commission pursuant to the requirements of 10 CFR 50.4 within thirty days of that determination. Other conditions that indicate possible effects on the integrity of two or more tendons shall be reportable in the same manner. Such reports shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedure and the corrective action taken.

5.6.8 Steam Generator Tube Inspection Report Point Beach 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 5.5.8, "Steam Generator (SG) Program." The report shall include:

a.

The scope of inspections performed on each SG;

b.

The nondestructive examination techniques utilized for tubes with increased degradation susceptibility;

c.

For each degradation mechanism found:

1.

The 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 5.6-6 Unit 1 - Amendment No. sO Unit 2 - Amendment No..aa.g.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.8 Point Beach Steam Generator Tube Inspection Report {continued) structures less than 20 percent through-wall, only the total number of indications needs to be reported;

3.

A description of the condition monitoring assessment and results, including the margin to the tube integrity performance criteria and comparison with the margin predicted to exist at the inspection by the previous forward-looking tube integrity assessment; and

4.

The number of tubes plugged during the inspection outage.

d.

An analysis summary of the tube integrity conditions predicted to exist at the next scheduled inspection (the forward-looking tube integrity assessment) relative to the applicable performance criteria, including the analysis methodology, inputs, and results;

e.

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

f.

The results of any SG secondary side inspections;

g.

For Unit 1 only, the primary to secondary leakage rate observed in each SG (if it is not practical to assign the leakage to an individual SG, the entire primary to secondary leakage should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report;

h.

For Unit 1 only, the calculated accident induced leakage rate from the portion of the tubes below 20.6 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident induced leakage rate from the most limiting accident is less than 5.22 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined; and

i.

For Unit 1 only, the results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.

5.6-7 Unit 1 - Amendment No. ~

Unit 2 - Amendment No. ~