ML17107A003

2017/04/10 NRR E-mail Capture - Beaver Valley Power Station, Unit 2 - Upcoming Steam Generator Tube Inservice Inspection (CAC No. MF9572)

ML17107A003
Person / Time
Site:	Beaver Valley
Issue date:	04/10/2017
From:	Booma Venkataraman Plant Licensing Branch 1
To:	Lashley P H FirstEnergy Corp
References
MF9572
Download: ML17107A003 (4)

Text

1NRR-PMDAPEm ResourceFrom:Venkataraman, BoomaSent:Monday, April 10, 2017 2:39 PMTo:Lashley, Phil H.Cc:Danna, James

Subject:

BEAVER VALLEY POWER STATION, UNIT 2 - UPCOMING STEAM GENERATOR TUBE INSERVICE INSPECTION (CAC NO. MF9572)Attachments:STEAM GENERATOR TUBE INSPECTION DISCUSSION POINTS.docxExpires:Friday, June 09, 2017 12:00 AMPhil, Inservice inspections of steam generator (SG) tubes play a vital role in assuring SG tube integrity. A telephone conference call has been arranged with you and members of your staff to discuss the ongoing results of the SG tube inspections to be conducted during the upcoming Beaver Valley Power Station, Unit 2, refueling outage. This call will occur after the majority of the tubes (approximately 70 percent) have been inspected, but before the SG inspection activities have been completed. Enclosed is a list of discussion points to facilitate this call.

The Nuclear Regulatory Commission (NRC) staff will document a summary of the conference call, including any material that you provide to the NRC staff in support of the call. If you have any questions regarding this matter, please contact me at 301-415-2934.

Sincerely, Booma Booma Venkataraman, P.E. Project Manager, NRR/DORL/LPL1 Office of Nuclear Reactor Regulation Booma.Venkataraman@nrc.gov 301.415.2934 Hearing Identifier: NRR_PMDA Email Number: 3438 Mail Envelope Properties (Booma.Venkataraman@nrc.gov20170410143900)

Subject:

BEAVER VALLEY POWER STATION, UNIT 2 - UPCOMING STEAM GENERATOR TUBE INSERVICE INSPECTION (CAC NO. MF9572) Sent Date: 4/10/2017 2:39:15 PM Received Date: 4/10/2017 2:39:00 PM From: Venkataraman, Booma Created By: Booma.Venkataraman@nrc.gov Recipients: "Danna, James" <James.Danna@nrc.gov> Tracking Status: None "Lashley, Phil H." <phlashley@firstenergycorp.com> Tracking Status: None Post Office: Files Size Date & Time MESSAGE 1029 4/10/2017 2:39:00 PM STEAM GENERATOR TUBE INSPECTION DISCUSSION POINTS.docx 25741 Options Priority: Standard Return Notification: No Reply Requested: No Sensitivity: Normal Expiration Date: 6/9/2017 Recipients Received:

STEAM GENERATOR TUBE INSPECTION DISCUSSION POINTS The following discussion points have been prepared to facilitate the conference call arranged with the licensee to discuss the results of the steam generator (SG) tube inspections to be conducted during the upcoming spring 2017, Beaver Valley Power Station, Unit 2, refueling outage. This conference call is scheduled to occur towards the end of the planned SG tube inspections, but before the inspections and repairs are completed. The Nuclear Regulatory Commission (NRC) staff plans to document a summary of the conference call, as well as any material that is provided in support of the call.

1. Discuss any trends in the amount of primary-to-secondary leakage observed during the recently completed cycle.

2. Discuss whether any secondary side pressure tests were performed during the outage and the associated results.

3. Discuss any exceptions taken to the industry guidelines. 4. For each SG, provide a description of the inspections performed including the areas examined and the probes used (e.g., dents/dings, sleeves, expansion-transition, U-bends with a rotating probe), the scope of the inspection (e.g., 100 percent of dents/dings greater than 5 volts and a 20 percent sample between 2 and 5 volts), and the expansion criteria. 5. For each area examined (e.g., tube supports, dent/dings, sleeves, etc.), provide a summary of the number of indications identified to date for each degradation mode (e.g., number of circumferential primary water stress-corrosion cracking (PWSCC) indications at the expansion transition). For the most significant indications in each area, provide an estimate of the severity of the indication (e.g., provide the voltage, depth, and length of the indication). In particular, address whether tube integrity (structural and accident induced leakage integrity) was maintained during the previous operating cycle.

In addition, discuss whether any location exhibited a degradation mode that had not previously been observed at this location at this unit (e.g., observed circumferential PWSCC at the expansion transition for the first time at this unit). 6. Describe repair/plugging plans.

7. Describe in-situ pressure test and tube pull plans and results (as applicable and if available). 8. Discuss the following regarding loose parts:

• what inspections are performed to detect loose parts;

• a description of any loose parts detected and their location within the SG (including the source or nature of the loose part, if known);

• if the loose parts were removed from the SG; and

• indications of tube damage associated with the loose parts 9. Discuss the scope and results of any secondary side inspection and maintenance activities (e.g., in-bundle visual inspections, feed-ring inspections, sludge lancing, assessing deposit loading, etc).

10. Discuss any unexpected or unusual results. 11. Provide the schedule for SG-related activities during the remainder of the current outage.