LR-N15-0001, Supplemental to License Amendment Request to Revise Technical Specifications to Adopt TSTF-510, Revision 2, Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection

Supplemental to License Amendment Request to Revise Technical Specifications to Adopt TSTF-510, Revision 2, Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection

ML15015A060
Person / Time
Site:	Salem   (DPR-070, DPR-075)
Issue date:	01/15/2015
From:	Jamila Perry Public Service Enterprise Group
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
LR-N15-0001 TSTF-510, Rev. 2
Download: ML15015A060 (11)

Text

PSEG Nuclear LLC P.O. Box 236, Hancocks Bridge, NJ 08038-0236 JAN 16 2015 LR-N15-0001 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Salem Generating Station, Units 1 and 2 Renewed Facility Operating License Nos. DPR-70 and DPR-75 NRC Docket Nos. 50-272 and 50-311 I

1\\/udNtr LLC 10 CFR 50.90

Subject:

Supplemental to License Amendment Request to Revise Technical Specifications to Adopt TSTF-510, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection"

References:

PSEG Letter LR-N14-0146, "License Amendment Request to Revise Technical Specifications to Adopt TSTF-51 0, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection" Using the Consolidated Line Item Improvement Process," dated July 28, 2014 By letter dated July 28, 2014, PSEG Nuclear, LLC (PSEG) submitted a proposed Technical Specification {TS) amendment for Salem Generating Station, Units 1 and 2. The proposed amendment would modify TS requirements regarding steam generator tube inspections and reporting as described in TSTF-510, Revision 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection."

This letter provides minor editorial corrections to the TS markups. There is no change or impact to the "No Significant Hazard Consideration" section that was submitted in the referenced license amendment request. describes the changes. Attachment 2 provides revised pages that reflect the changes described in Attachment 1.

There are no regulatory commitments contained in this letter.

If you have any questions or require additional information, please contact Ms. Tanya Timberman at 856-339-1426.

LR-N15-0001 Page 2 I declare under penalty of perjury that the foregoing is true and correct.

Executed on ----'-Y_I_L\\-..£...

/_1_5" (Date)

Respectfully,

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John F. Perry Site Vice President-S em Generating Station Attachments:

1. Description of Changes

2. Technical Specification Pages Incorporating Proposed Changes cc:

Mr. D. Dorman, Administrator, Region I, NRC Ms. C. Sanders-Parker, Project Manager, NRC

' NRC Senior Resident Inspector, Salem Mr. P. Mulligan, Manager IV, NJBNE PSEG Corporate Commitment Tracking Coordinator Salem Commitment Tracking Coordinator 10 CFR 50.90

LR-N15-0001 Description of Changes

LR-N15-0001 Changes to Previously Submitted Technical Specification Mark-up Pages Salem Unit 1

1. TS 6.8.4.i.b.1, on page 6-19c, was changed to insert a hyphen for the word "in-service."

2.

The third sentence in Insert #1 to TS 6.8.4.i.d.2, on page 6-19d, was changed to revise "that" to "the" and "inspected" to "the inspection". The third sentence now reads (revised words in bold for illustrative purposes only):

"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 criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated."

3. TS 6.9.1.1 O.f, on page 6-24a, was changed to correctly spell the word "effective" and to remove the word "and" at the end of the statement.

Salem Unit 2

1. TS 6.8.4.i.b.1, on page 6-19c, was changed to insert a hyphen for the word "in-service."

1

LR*N15-0001 Technical Specification Pages Incorporating Proposed Changes

LRDN15-0001 The following Technical Specifications pages for Renewed Facility Operating License DPR-70 are affected by this change request:

Technical Specification 6.8.4.i, Steam Generator (SG) Program 6.9.1 0, Steam Generator Tube Inspection Report 6-19c 6-19d 6-24a The following Technical Specifications pages for Renewed Facility Operating License DPR-75 are affected by this change request:

Technical Specification 6.8.4.i, Steam Generator (SG) Program 6-19c

ADMINISTRATIVE CONTROLS 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

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i -n-- s-e-rv-: i -ce-s-:--

te_a_m---, meeting the performance criteria for tube structural integrity, accident induced leakage, generator tubes shall and operational leakage.

retain structural

1.

Structural integrity performance criterion: 1\\11 in service steam generator tubes integrity over the full shall retain structural integrity over the full range of normal operating conditio-ns range of normal (tncluding startup, operation in tho po'Ner range, hot standby, and cool down and operating conditions all anticipated transients inoluded in tho design specification) and design basis (including startup, accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure operation in the differential and a safety factor of 1.4 against burst applied to tho design basis power range, hot accident primary-to-secondary pressure differentials. Apart from the above standby, and cool requirements, additional loading conditions associated with the design basis down), all anticipated accidents, or combination of accidents in accordance with the design and transients included in licensing basis, shall also be evaluated to determine if the associated loads the design 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 specification, and assessed in combination with the loads due to pressure with a safety factor of 1.2 design basis on the combined primary loads and 1.0 on axial secondary loads.

accidents.

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 8Gs and leakage rate for an individual SG.

Leakage is not to exceed 1 gallon per minute per SG.

3.

The operational leakage performance criterion is specified in LCO 3.4.6.2, "Reactor Coolant System 0 erational Leakage."

plugging

c.

Provisions for SG tube Fe-** critena.

u es 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 FOJ*lif criteria shall be applied as an alternative to the 40% depth based criteria:

1.

Tubes with service3/4induced flaws located greater than 15.21 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 15.21 inches below the top of the tubesheet shall be plugged upon detection.

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

• criteria.

SALEM

• UNIT 1 Amendment No. 303

ADMINISTRATIVE CONTROLS The portion of the tube below 15.21 inches from the top of the tubesheet is excluded from this requirement.

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 assesment of degradation shall be performed to determine the type and location of I' s to which th ubes may be susceptible and, based on this assessment, to determi e which Inspection ethods need to be employed and at what locations.

degradation assessment

1.

2.

INSERT: "affected and potentially affected"

3.

results in more frequent inspections Inspect 100% of the tubes in each SG during the first refueling outage following SG replaoement.installation. I Inspect 100% of the tubes at sequential periods of 120, 90, and thereafter, 60 effective full povt'er months. The first sequential period shall be oonsidered to begin after the first inservioe 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 t\\vo refueling



If crack indications found in portions of the SG tub not excluded above, then the next inspection for ea SG for the degradation m chanism that caused the crack indication shall not exceed 24 effective full pow r months or one refueling outage (whichever *

). If definitive information, s ch as from examination of a pulle 1agnostic non²destructive testing, or e gineering evaluation 1cates that a crack-like indication is not associated ith a crack(s), then the indication need not be treated as a crack.

e.

Provisions for monitoring operational primary-to-secondary le kage.

DELETE AND REPLACE FR OM INSERT #1 SALEM-UNIT 1 6-19d Amendment No. 303

Insert #1 Salem Unit 1 6.8.4.i.d.2/ page 6-19d "After the first refueling outage following SG installation, inspect each SG at least every 48 effective full power months 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 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.

a)

After the first refueling outage following SG installation, inspect 1 00% of the tubes during the next 1 20 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 1 00% of the tubes every 72 effective full power months. This constitutes the third and subsequent inspection periods."

ADMINISTRATIVE CONTROLS

2. WCAP-8385, Power Distribution Control and Load Following Procedures - Topical Report,

( Proprietary)

Methodology for Specification 3/4.2.1 Axial Flux Difference.

3. WCAP-10054-P-A, Westinghouse Small Break ECCS Evaluation Model Using NOTRUMP Code (W Proprietary),

Methodology for Specification 3/4.2.2 Heat Flux Hot Channel Factor.

4. WCAP-10266-P-A, The 1981 Version of Westingouse Evaluation Model Using BASH Code,

( Proprietary)

Methodology for Specification 3/4.2.2 Heat Flux Hot Channel Factor.

5. WCAP-12472-P-A, BEACON -

Core Monitoring and Operations Support

System,

( Proprietary}.

6. CENPD-397-P-A, Improved Flow Measurement Accuracy Using Crossflow Ultrasonic Flow Measurement Technology.

c.

The core operating limits shall be determined such that all applicable limits (e.g.,

fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS}

limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits}

of the safety analysis are met.

d.

The COLR, including any mid-cycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

6.9.1.10 STEAM GENERATOR TUBE INSPECTION REPORT A report shall be submitted within 180 days after the initial entry into HOT SHUTDOWN following completion of an inspection performed in accordance with the Specification 6.8.4.i,

• steam Generator (SG)

Program.u The report shall include:

DELETE

a.

The scopespections performed on each SG,

grtion mechanisms found, Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear) 1 and measured sizes (if available) of service induced indications,

e.

Number of tubes plugged during the inspection outage for each

 eret.-4-v-e degradation mechanism,

f.

tubes plussed to date, &ad

g.

The results of con

'tion monitoring, including the results of tube pulls and in-situ t ting.

SALEM UNIT 1

&------'----,----(----)*+--,-------*

The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator, 6-24a Amendment No.

284

ADMINISTRATIVE CONTROLS

a.

Provisions for condition monitoring assessments, Condition

monitoring ass essment means an evaluation of the "as found "

condition of the tubing with respect to the performance criteria for structural integrity and a ccident induced leakage.

The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the i nservice inspection results or by other means, prior to the plugging of tubes.

Condition monitoring assessments shall be condu cted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.

b.

All in-service steam generator tubes shall retain structural 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:

Fdl in servioo integrity over the full s-t:-e-a-m gene:rate:r tubes shall retain structural integrity over range of normal the full range of normal operating conditions (including operating conditions _j startup, operati!n. in the poHe+ rang?,

hat stndby, and eool (including startup dovm and all anho1:pated ranDlents 1:ncluded H! the de:ngn specification) and desigfi basis accidents.

This includes operation In the power retaining a safety factor of 3. 0 against burst under normal range, hot standby, steady state full power operation primary-to-secondary pressure and cool down), all differential and a safety factor of 1. 4 against burst applied anticipated transients to the design basis accident primary-to-secondary pressure differentials.

Apart from the above requirements, additional Included In the design loading conditions associated with the design basis accidents, specification, and or combination of accidents in accordance with the design and design basis licensing basis, shall also be evaluated to determine if the accidents associ ated 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 combina*tion 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.

c.

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 t.he leakage rate assumed in the accident analysis in terms of total le akage rate for all SGs and le akage rate for an individual SG.

Leakage is not to exceed 1 gal lon per minute per SG.

3.

The LCO specified in Leakage."

Tubes found by inservice equal to or exceeding 40%

be plugged.

SALEM -

UNIT 2 6-19c Amendment No.

262