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| number = ML14028A256
| number = ML14028A256
| issue date = 01/23/2014
| issue date = 01/23/2014
| title = Surry, Unit 2, Response to Request for Clarifying Information Regarding Steam Generator Tube Inservice Inspection Report for the Fall 2012 Refueling Outage
| title = Response to Request for Clarifying Information Regarding Steam Generator Tube Inservice Inspection Report for the Fall 2012 Refueling Outage
| author name = Lane N L
| author name = Lane N
| author affiliation = Virginia Electric & Power Co (VEPCO)
| author affiliation = Virginia Electric & Power Co (VEPCO)
| addressee name =  
| addressee name =  
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=Text=
=Text=
{{#Wiki_filter:VIRGINIA ELECTRIC AND POWER COMPANYRICHMOND, VIRGINIA 23261January 23, 2014U. S. Nuclear Regulatory Commission Attention:
{{#Wiki_filter:VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 January 23, 2014 U. S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, DC 20555-0001 Serial No.:
Document Control DeskWashington, DC 20555-0001 Serial No.:SPS-LIC/CGL:
SPS-LIC/CGL:
Docket Nos.:License Nos.:13-237ARO50-281DPR-37VIRGINIA ELECTRIC AND POWER COMPANYSURRY POWER STATION UNIT 2RESPONSE TO REQUEST FOR CLARIFYING INFORMATION REGARDING STEAM GENERATOR TUBE INSERVICE INSPECTION REPORTFOR THE FALL 2012 REFUELING OUTAGEIn a letter dated May 10, 2013 (Serial No. 13-237),
Docket Nos.:
Virginia Electric and PowerCompany (Dominion) submitted information summarizing the results of steam generator (SG) tube inspections performed at Surry Power Station Unit 2 during the Fall 2012refueling outage. In a September 17, 2013 e-mail from Ms. Karen Cotton Gross(NRC Project Manager) to Mr. Gary D. Miller (Dominion Corporate Licensing),
License Nos.:
the NRCstaff requested clarifying information related to the SG inspections.
13-237A RO 50-281 DPR-37 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 RESPONSE TO REQUEST FOR CLARIFYING INFORMATION REGARDING STEAM GENERATOR TUBE INSERVICE INSPECTION REPORT FOR THE FALL 2012 REFUELING OUTAGE In a {{letter dated|date=May 10, 2013|text=letter dated May 10, 2013}} (Serial No. 13-237), Virginia Electric and Power Company (Dominion) submitted information summarizing the results of steam generator (SG) tube inspections performed at Surry Power Station Unit 2 during the Fall 2012 refueling outage.
On January 13, 2014, an NRC -Dominion conference call was held to discuss theDominion responses previously provided to the NRC. The NRC's questions andDominion's responses are provided in the attachment to this letter.If you have further questions or require additional information, Ms. Candee Lovett at (757) 365-2178.
In a September 17, 2013 e-mail from Ms. Karen Cotton Gross (NRC Project Manager) to Mr. Gary D. Miller (Dominion Corporate Licensing), the NRC staff requested clarifying information related to the SG inspections.
please contactSincerely, i)1'N. L. LaneSite Vice President Surry Power StationCommitments contained in this letter: None
On January 13, 2014, an NRC -
Dominion conference call was held to discuss the Dominion responses previously provided to the NRC.
The NRC's questions and Dominion's responses are provided in the attachment to this letter.
If you have further questions or require additional information, Ms. Candee Lovett at (757) 365-2178.
please contact Sincerely, i) 1*'
N. L. Lane Site Vice President Surry Power Station Commitments contained in this letter: None


==Attachment:==
==Attachment:==
Response to NRC Request for Clarifying Information Regarding Fall 2012 Steam Generator Inservice Inspection Report - Surry Power Station Unit 2


Response to NRC Request for Clarifying Information Regarding Fall 2012Steam Generator Inservice Inspection Report -Surry Power Station Unit 2 Serial No. 13-237ADocket Nos. 50-281Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection ReportPage 2 of 2cc: U.S. Nuclear Regulatory Commission  
Serial No. 13-237A Docket Nos. 50-281 Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection Report Page 2 of 2 cc:
-Region IIMarquis One Tower245 Peachtree Center Avenue, NE Suite 1200Atlanta, GA 30303-1257 Ms. K. R. Cotton GrossNRC Project Manager SurryU.S. Nuclear Regulatory Commission One White Flint NorthMail Stop 08 G-9A11555 Rockville PikeRockville, MD 20852-2738 Dr. V. Sreenivas NRC Project Manager North AnnaU.S. Nuclear Regulatory Commission One White Flint NorthMail Stop 08 G-9A11555 Rockville PikeRockville, MD 20852-2738 NRC Senior Resident Inspector Surry Power StationMr. R. A. SmithAuthorized Nuclear Inspector Surry Power Station Serial No. 13-237ADocket Nos. 50-281Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection ReportAttachment Response to NRC Request for Clarifying Information Regarding Fall 2012 Steam Generator Inservice Inspection Report -Surry Power Station Unit 2Virginia Electric and Power Company(Dominion)
U.S. Nuclear Regulatory Commission - Region II Marquis One Tower 245 Peachtree Center Avenue, NE Suite 1200 Atlanta, GA 30303-1257 Ms. K. R. Cotton Gross NRC Project Manager Surry U.S. Nuclear Regulatory Commission One White Flint North Mail Stop 08 G-9A 11555 Rockville Pike Rockville, MD 20852-2738 Dr. V. Sreenivas NRC Project Manager North Anna U.S. Nuclear Regulatory Commission One White Flint North Mail Stop 08 G-9A 11555 Rockville Pike Rockville, MD 20852-2738 NRC Senior Resident Inspector Surry Power Station Mr. R. A. Smith Authorized Nuclear Inspector Surry Power Station
Serial No. 13-237ADocket Nos. 50-281Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection ReportPage 1 of 1NRC Question 1The report dated May 10, 2013, states that this was the second inspection in the4th inspection period and that the steam generators had operated for 301.8 effective fullpower months (EFPMs).
 
The first, second, and third sequential inspection periods are'120, 96, and 72 EFPMs with the first sequential inspection period beginning after thefirst inservice inspection.
Serial No. 13-237A Docket Nos. 50-281 Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection Report Attachment Response to NRC Request for Clarifying Information Regarding Fall 2012 Steam Generator Inservice Inspection Report -
Assuming the first inspection took place after 13 EFPMs, thiswould mean that the steam generators have operated at least 301 EFPM. If this wasthe 2nd inspection in the fourth sequential period, it would mean that 2 inspections wereperformed in a 0.8 EFPM interval.
Surry Power Station Unit 2 Virginia Electric and Power Company (Dominion)
Please discuss how the current inspection periodwas determined.
 
Dominion ResponseThe NRC question states that the first, second, and third inspection periods are120 EFPM, 90 EFPM, and 72 EFPM, respectively.
Serial No. 13-237A Docket Nos. 50-281 Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection Report Page 1 of 1 NRC Question 1 The report dated May 10, 2013, states that this was the second inspection in the 4 th inspection period and that the steam generators had operated for 301.8 effective full power months (EFPMs). The first, second, and third sequential inspection periods are
These inspection period durations are the current TS 6.4.Q.4.b requirements, which became effective on March 20, 2013when TS Amendments 278/278 were implemented.
'120, 96, and 72 EFPMs with the first sequential inspection period beginning after the first inservice inspection. Assuming the first inspection took place after 13 EFPMs, this would mean that the steam generators have operated at least 301 EFPM. If this was the 2 nd inspection in the fourth sequential period, it would mean that 2 inspections were performed in a 0.8 EFPM interval. Please discuss how the current inspection period was determined.
TS Amendments 278/278approved SG Program revisions in accordance with TSTF-510 Revision  
Dominion Response The NRC question states that the first, second, and third inspection periods are 120 EFPM, 90 EFPM, and 72 EFPM, respectively. These inspection period durations are the current TS 6.4.Q.4.b requirements, which became effective on March 20, 2013 when TS Amendments 278/278 were implemented.
: 2. Our requestto adopt the TSTF-510 Program revisions was transmitted by letter Serial No. 12-487,dated July 31, 2012, and TS Amendments 278/278 were issued on January 28, 2013.Prior to the implementation of TS Amendments 278/278, the inspection period durations required by TS 6.4.Q.4.b for the first, second, and third inspection periods were120 EFPM, 90 EFPM, and 60 EFPM, respectively.
TS Amendments 278/278 approved SG Program revisions in accordance with TSTF-510 Revision 2. Our request to adopt the TSTF-510 Program revisions was transmitted by letter Serial No. 12-487, dated July 31, 2012, and TS Amendments 278/278 were issued on January 28, 2013.
The SG inspections conducted during the Unit 2 Fall 2012 were the second of four scheduled for the 4th inspection period, which was 60 EFPM. The shortest period between inspections for Unit 2 was12.94 EFPM. Based on this clarification of the inspection period durations, the 301.8EFPM value (since the first inservice inspection) is verified to be correct.NRC Question 2Please discuss the extent of the inspection and analysis of the array probe datacollected within the tubesheet/expansion transition region.Dominion ResponseDuring the Unit 2 Fall 2012 refueling outage, 100 percent of the tubes in both the hot legand cold leg in SG "A" was examined with the array probe from either the baffle plate orthe tube support plate to the tube end. Analysis excluded the area below the H-stardepth of 17.89 inches in accordance with the alternate tube plugging criteria reflected inTS 6.4.Q.3.b.
Prior to the implementation of TS Amendments 278/278, the inspection period durations required by TS 6.4.Q.4.b for the first, second, and third inspection periods were 120 EFPM, 90 EFPM, and 60 EFPM, respectively.
The SG inspections conducted during the Unit 2 Fall 2012 were the second of four scheduled for the 4 th inspection period, which was 60 EFPM. The shortest period between inspections for Unit 2 was 12.94 EFPM. Based on this clarification of the inspection period durations, the 301.8 EFPM value (since the first inservice inspection) is verified to be correct.
NRC Question 2 Please discuss the extent of the inspection and analysis of the array probe data collected within the tubesheet/expansion transition region.
Dominion Response During the Unit 2 Fall 2012 refueling outage, 100 percent of the tubes in both the hot leg and cold leg in SG "A" was examined with the array probe from either the baffle plate or the tube support plate to the tube end. Analysis excluded the area below the H-star depth of 17.89 inches in accordance with the alternate tube plugging criteria reflected in TS 6.4.Q.3.b.
No issues were identified through the tubesheet/expansion transition region to the H-star depth.}}
No issues were identified through the tubesheet/expansion transition region to the H-star depth.}}

Latest revision as of 23:37, 10 January 2025

Response to Request for Clarifying Information Regarding Steam Generator Tube Inservice Inspection Report for the Fall 2012 Refueling Outage
ML14028A256
Person / Time
Site: Surry Dominion icon.png
Issue date: 01/23/2014
From: Lane N
Virginia Electric & Power Co (VEPCO)
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
13-237A
Download: ML14028A256 (4)
v • d • e


Text

VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 January 23, 2014 U. S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, DC 20555-0001 Serial No.:

SPS-LIC/CGL:

Docket Nos.:

License Nos.:

13-237A RO 50-281 DPR-37 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 RESPONSE TO REQUEST FOR CLARIFYING INFORMATION REGARDING STEAM GENERATOR TUBE INSERVICE INSPECTION REPORT FOR THE FALL 2012 REFUELING OUTAGE In a letter dated May 10, 2013 (Serial No.13-237), Virginia Electric and Power Company (Dominion) submitted information summarizing the results of steam generator (SG) tube inspections performed at Surry Power Station Unit 2 during the Fall 2012 refueling outage.

In a September 17, 2013 e-mail from Ms. Karen Cotton Gross (NRC Project Manager) to Mr. Gary D. Miller (Dominion Corporate Licensing), the NRC staff requested clarifying information related to the SG inspections.

On January 13, 2014, an NRC -

Dominion conference call was held to discuss the Dominion responses previously provided to the NRC.

The NRC's questions and Dominion's responses are provided in the attachment to this letter.

If you have further questions or require additional information, Ms. Candee Lovett at (757) 365-2178.

please contact Sincerely, i) 1*'

N. L. Lane Site Vice President Surry Power Station Commitments contained in this letter: None

Attachment:

Response to NRC Request for Clarifying Information Regarding Fall 2012 Steam Generator Inservice Inspection Report - Surry Power Station Unit 2

Serial No. 13-237A Docket Nos. 50-281 Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection Report Page 2 of 2 cc:

U.S. Nuclear Regulatory Commission - Region II Marquis One Tower 245 Peachtree Center Avenue, NE Suite 1200 Atlanta, GA 30303-1257 Ms. K. R. Cotton Gross NRC Project Manager Surry U.S. Nuclear Regulatory Commission One White Flint North Mail Stop 08 G-9A 11555 Rockville Pike Rockville, MD 20852-2738 Dr. V. Sreenivas NRC Project Manager North Anna U.S. Nuclear Regulatory Commission One White Flint North Mail Stop 08 G-9A 11555 Rockville Pike Rockville, MD 20852-2738 NRC Senior Resident Inspector Surry Power Station Mr. R. A. Smith Authorized Nuclear Inspector Surry Power Station

Serial No. 13-237A Docket Nos. 50-281 Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection Report Attachment Response to NRC Request for Clarifying Information Regarding Fall 2012 Steam Generator Inservice Inspection Report -

Surry Power Station Unit 2 Virginia Electric and Power Company (Dominion)

Serial No. 13-237A Docket Nos. 50-281 Response to Request for Clarifying Information Regarding Unit 2 Fall 2012 SG Inservice Inspection Report Page 1 of 1 NRC Question 1 The report dated May 10, 2013, states that this was the second inspection in the 4 th inspection period and that the steam generators had operated for 301.8 effective full power months (EFPMs). The first, second, and third sequential inspection periods are

'120, 96, and 72 EFPMs with the first sequential inspection period beginning after the first inservice inspection. Assuming the first inspection took place after 13 EFPMs, this would mean that the steam generators have operated at least 301 EFPM. If this was the 2 nd inspection in the fourth sequential period, it would mean that 2 inspections were performed in a 0.8 EFPM interval. Please discuss how the current inspection period was determined.

Dominion Response The NRC question states that the first, second, and third inspection periods are 120 EFPM, 90 EFPM, and 72 EFPM, respectively. These inspection period durations are the current TS 6.4.Q.4.b requirements, which became effective on March 20, 2013 when TS Amendments 278/278 were implemented.

TS Amendments 278/278 approved SG Program revisions in accordance with TSTF-510 Revision 2. Our request to adopt the TSTF-510 Program revisions was transmitted by letter Serial No.12-487, dated July 31, 2012, and TS Amendments 278/278 were issued on January 28, 2013.

Prior to the implementation of TS Amendments 278/278, the inspection period durations required by TS 6.4.Q.4.b for the first, second, and third inspection periods were 120 EFPM, 90 EFPM, and 60 EFPM, respectively.

The SG inspections conducted during the Unit 2 Fall 2012 were the second of four scheduled for the 4 th inspection period, which was 60 EFPM. The shortest period between inspections for Unit 2 was 12.94 EFPM. Based on this clarification of the inspection period durations, the 301.8 EFPM value (since the first inservice inspection) is verified to be correct.

NRC Question 2 Please discuss the extent of the inspection and analysis of the array probe data collected within the tubesheet/expansion transition region.

Dominion Response During the Unit 2 Fall 2012 refueling outage, 100 percent of the tubes in both the hot leg and cold leg in SG "A" was examined with the array probe from either the baffle plate or the tube support plate to the tube end. Analysis excluded the area below the H-star depth of 17.89 inches in accordance with the alternate tube plugging criteria reflected in TS 6.4.Q.3.b.

No issues were identified through the tubesheet/expansion transition region to the H-star depth.

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