Text

Inservice Inspection (ISI) and Steam Generator Inspection (SG-ISI) Report
	ML21214A160
Person / Time
Site:	Catawba
Issue date:	08/02/2021
From:	Hare M; Duke Energy Carolinas
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	RA-21-0223
	Download: ML21214A160 (35)
	v • d • e

Mandy Hare Nuclear Support Services Manager Catawba Nuclear Station Duke Energy CN03CH l 4800 Concord Rd York, SC 29745 803.701.2218 Mandy.Hare@duke-energy.com Serial: RA-21-0223 August 2, 2021 United States Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Catawba Nuclear Station, Unit No. 2 Docket No. 50-414 / Renewed License No. NPF-52

Subject:

Catawba Unit 2, Refuel 24 (C2R24) Inservice Inspection (ISI) and Steam Generator Inspection (SG-ISI) Report Ladies and Gentlemen:

In accordance with Section XI of the American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel Code, Duke Energy is providing its Inservice Inspection (ISI) Summary Report for Catawba Nuclear Station, Unit No. 2, Refuel 24 (C2R24). Also included is the Steam Generator Inservice Inspection (SG-ISI) Summary Report for Catawba Nuclear Station, Unit No.

2, Refuel 24 (C2R24).

contains the C2R24 Owners Activity Summary Report.

contains the SG-ISI tube inspection report for C2R24.

This submittal contains no regulatory commitments. Should you have any questions concerning this letter, or require additional information, please contact Art Zaremba, Manager - Nuclear Fleet Licensing, at 980-373-2062.

Sincerely, Mandy Hare Nuclear Support Services Manager, Catawba Nuclear Station

(., DUKE ENERGY

U.S. Nuclear Regulatory Commission Page 2 Serial: RA-21-0223 Enclosure(s):

1. Owners Activity Summary Report For Refueling Outage 24

2. Steam Generator Inservice Inspection Report For Refueling Outage 24 NDE cc:

(w/ all enclosures)

K. Cotton, NRC Project Manager, NRR cc:

(without SG data)

L. Dudes, NRC Regional Administrator, Region II J.D. Austin, NRC Senior Resident Inspector, Catawba Nuclear Station Serial: RA-21-0223 Owners Activity Summary Report for Refueling Outage 24

DUKE ENERGY INSERVICE INSPECTION

SUMMARY

REPORT UNIT 2 CATAWBA 2021 REFUELING OUTAGE C2R24 (Outage 24)

Location: 4800 Concord Road, York, SC, 29745 NRC Docket No. 50-414 Commercial Service Date: August 19, 1986 Owner: Duke Energy 526 South Church St.

Charlotte, NC 28201-1006 Revision 0 Originated By:

Checked By:

Approved By:

TDM8384 (130489) dc=com, dc=duke-energy, dc=ent, dc=nam, ou=Accounts, ou=Personal, ou=PNTransitional, en= TDM8384 (130489), email= Timothy.Myers@duke-energy.com 2021.07.21 09:56:00 -04'00' SLM410S (137S06) dc=com, dc=duke-energy, dc=ent, dc=nam, ou=Accounts, ou=Personal, ou=PNTransitional, cn=SLM4105 (137506), email=Steve.Mays@duke-energy.com 2021.07.2111:08:16-04'00' MAP9681 (102140)

Digitally signed by MAP9681 (102140)

Date: 2021.07.21 12:02:21 -04'00'

CASE N-532-5 Page 1 of 4 FORM OAR-1 OWNER'S ACTIVITY REPORT Report Number r Refueling Outage C2R24 Plant Catawba Nuclear Station, 4800 Concord Road, York, SC 29745 Unit No.

2 Commercial service date August 19, 1986 Refueling outage no.

C2R24 (if applicable)

Current inspection interval Fourth Inspection Interval (ISI), Third Inspection Interval (Containment ISI)

(1st, 2nd, 3rd, 4th, other)

Current inspection period Second Inspection Period (ISI and Containment ISI)

(1st, 2nd, 3rd)

Edition and Addenda of Section XI applicable to the inspection plans ASME Section XI 2007 Edition through 2008 Addenda Date and revision of inspection plans See Attachment - Page 2 Edition and Addenda of Section XI applicable to repair/replacement activities, if different than the inspection plans Same as above Code Cases used for inspection and evaluation:

The following Code Cases are permitted by the ISI Plan and Addenda:

4th Interval: N-513-3, N-532-5, N-586-1, N-600, N-613-1, N-639, N-643-2, N-648-1, N-651, N-705, N-706-1, N-712, N-716-1, N-722-1, N-729-6, N-731, N-735, N-747, N-751, N-765, N-770-5, N-771, N-775, N-776, N-786-1, N-798, N-800, N-805, N-823, N-825, N-843, N-845 & N-854 (if applicable)

CERTIFICATE OF CONFORMANCE I certify that (a) the statements made in this report are correct; (b) the examinations and tests meet the Inspection Plan as required by the ASME Code,Section XI; and (c) the repair/replacement activities and evaluations supporting the completion of C2R24 conform to the requirements of Section XI.

(refueling outage number)

Signed Tim Myers, ISI Program Owner Date CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of South Carolina and employed by OneCIS Insurance Company Lynn, MA have inspected has performed all activities represented by this report in accordance with the requirements of Section XI.

By signing this certificate neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the repair/replacement activities and evaluation described in this report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this inspection.

Commissions National Board, State, Province, and Endorsements Date Dustin Mallet 15196 AI, IS, I, N, R; SC 363 07/21/2021 Owner's Activity Report fo TDM8384 (130489) dc=com, dc=duke-energy, dc=ent, dc=nam, ou=Accounts, ou=Personal, ou=PNTransitional, en= TDM8384 (130489), email= Timothy.Myers@duke-energy.com 2021.07.21 09:56:27 -04'00' the items described in this Owner's Activity Report, and state that, to the best of my knowledge and belief, the Owner

?

Inspector's Signature

CASE N-532-5 Page 2 of 4 Attachment Catawba Unit 2 Refuel Outage 24, Inservice Inspection Report The Catawba Nuclear Station Unit 2 Fourth Ten Year Inservice Inspection (ISI) Plan complies with 10CFR50.55a(g), (79 FR 73462, Dec. 11, 2014), which implements, by reference, the American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel Code,Section XI, 2007 Edition with 2008 Addenda.

This summary report is being submitted pursuant to the reporting requirements of ASME Section XI as ement Activity Documentation Requirements and Contained within this summary report are the form OAR-Code Case N-532-5 for Catawba Nuclear Station during cycle 24 and Refueling Outage 24 (C2R24).

C2R24 is the second outage of the second ISI period in the fourth inspection interval. C2R24 is the second outage of the second Containment period in the third inspection interval. This report reviewed all Repair/Replacement activities from October 10, 2019 through May 3, 2021, cycle 24.

Date and Revision of Inservice Inspection Plans:

I.

Fourth Interval Inservice Inspection Plans

1. The following documents comprise the Catawba Nuclear Station 4th Interval Inservice Inspection Plan for Unit 2 (Class 1, 2, and 3 Components):

Document #CISI-1462.10-0040-ISI PLAN, Rev. 6, dated 01/11/2021.

b. Fourth Interval Inservice Inspection Outage Schedule Catawba Nuclear Station Unit 2, Document #CISI-1462.10-0040-UNIT 2, Rev. 3, dated 01/11/2021.

2. The following documents comprise the Catawba Nuclear Station 4th Interval Inservice Inspection Pressure Test Plan for Unit 2:

a. Catawba Nuclear Station Units 1 and 2 Fourth Inspection Interval Inservice Inspection Pressure Test Plan, Document #CISI-1462.20.0040-PTPlan, Rev. 2, dated 11/18/2020.

II.

Third Interval Containment Inservice Inspection Plan

1. The following document comprises the Catawba Nuclear Station 3rd Interval Containment Inservice Inspection Plan for Unit 1 (Class MC):

a. Catawba Nuclear Station Units 1 and 2 - Third Interval Containment Inservice Inspection Plan, Document #CN-ISIC3-1042-0001, Rev. 10, dated 11/19/2020.

amended by ASME Code Case N-532-5, "Repair/Replac lnservice Inspection Summary Report Preparation and Submission Section XI, Division 1 ".

1 (Owner's Activity Report) and Tables 1 and 2 of

a. Catawba Nuclear Station Unit 1 and Unit 2 - Fourth Interval lnservice Inspection Plan,

CASE N-532-5 Page 3 of 4 TABLE 1 ITEMS WITH FLAWS OR RELEVANT CONDITIONS THAT REQUIRED EVALUATION FOR CONTINUED SERVICE Examination Category and Item Number Item Description Evaluation Description C-H I C7.10 Boric acid residue found during ISI Pressure Test Zone, 2NI-003L-B Area identified in NCR #02349250 was evaluated by Engineering and found to be acceptable.

C-H I C7.10 Boric acid residue found during ISI Pressure Test Zone, 2NI-005L-B Area identified in NCR #02333771 was evaluated by Engineering and found to be acceptable.

C-H I C7.10 Boric acid residue found during ISI Pressure Test Zone, 2NS-001L-B Area identified in NCR #02342929 was evaluated by Engineering and found to be acceptable.

C-H I C7.10 Boric acid residue found during ISI Pressure Test Zone, 2NV-002L-B Area identified in NCR #02334790 was evaluated by Engineering and found to be acceptable.

C-H I C7.10 Boric acid residue found during ISI Pressure Test Zone, 2NV-005L-B Area identified in NCR #02343794 was evaluated by Engineering and found to be acceptable.

C-H I C7.10 Boric acid residue found during ISI Pressure Test Zone, 2NV-006L-B Area identified in NCR #02345784 was evaluated by Engineering and found to be acceptable.

C-H I C7.10 Boric acid residue found during ISI Pressure Test Zone, 2NS-002L-B Area identified in NCR #02354578 was evaluated by Engineering and found to be acceptable.

D-B I D2.10 Boric acid residue found during ISI Pressure Test Zone, 2KF-001L-C Area identified in NCR #02334792 was evaluated by Engineering and found to be acceptable.

D-B I D2.10 Boric acid residue found during ISI Pressure Test Zone, 2KF-002L-C Area identified in NCR #02361262 was evaluated by Engineering and found to be acceptable.

D-B I D2.10 Boric acid residue found during ISI Pressure Test Zone, 2NV-001L-C Area identified in NCR #02345142 was evaluated by Engineering and found to be acceptable.

F-A / F1.12 Cold load setting on variable spring support 2-R-ND-1000 found out of tolerance Out of tolerance setting identified in NCR # 02377769 was evaluated by Engineering and found to be acceptable.

CASE N-532-5 Page 4 of 4 TABLE 2 ABSTRACT OF REPAIR/REPLACEMENT ACTIVITIES REQUIRED FOR CONTINUED SERVICE Code Class Item Description Description of Work Date Completed Repair /

Replacement Plan Number 1

2NC-HX-B 2B SG Tube plugging 4/14/2021 20415442-05 1

2NC-HX-C 2C SG Tube plugging 4/14/2021 20415443-05 1

2NC-HX-D 2D SG Tube plugging 4/14/2021 20415445-05 3

Nuclear Service Water System piping Replace 2" pipe downstream and upstream of valve 1RN24 due to pin hole leaks 10/27/2020 20426186-01 1

2NC-RX-HEAD Perform weld overlay of RVH pen #74 defect per WCAP-15987-P (See Relief Request RA-21-0133) 4/26/2021 20461807-09 Serial: RA-21-0223 Steam Generator Inservice Inspection Report for Refueling Outage 24

Steam Generator In-service Inspection Summary Report Catawba Nuclear Station Unit 2 EOC-24 April 2021 Location: 4800 Concord Road, York South Carolina 29745 NRC Docket No. 50-414 \\ License No. NPF-52 National Board No. 173 Commercial Service Date: August 19, 1986 Owner:

Duke Energy Corporation 526 South Church St.

Charlotte, N.C. 28201-1006 Revision 0 Prepared By: Dan Mayes Date: __________________

Reviewed By: Tim Thulien Date: __________________

Approved By: Etienne Fonteneau Date: __________________

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FORM OAR-1 OWNERS ACTIVITY REPORT Report Number Owners Activity Report for Steam Generator Inspection Outage EOC-24 Plant Catawba Nuclear Station, 4800 Concord Road, York, SC 29745 Unit No.

2 Commercial service date 08/19/1986 Refueling outage no.

EOC-24 (if applicable)

Current inspection interval Fourth Interval (1st, 2nd, 3rd, 4th, other)

Current inspection period Second Period (1st, 2nd, 3rd)

Edition and Addenda of Section XI applicable to the inspection plans 2007 Edition through 2008 Addendum Date and revision of inspection plans August 19, 2015, Revision 0 (Document #C-ISIG-0169.030.0040)

Edition and Addenda of Section XI applicable to repair/replacement activities, if different than the inspection plans Same as Plan Code Cases used:

N-532-5 (if applicable)

CERTIFICATE OF CONFORMANCE I certify that (a) the statements made in this report are correct; (b) the examinations and tests meet the Inspection Plan as required by the ASME Code,Section XI; and (c) the repair/replacement activities and evaluations supporting the completion of EOC-24 conform to the requirements of Section XI.

(refueling outage number)

Signed D.B. Mayes Date 7/21/2021 CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of South Carolina and employed by OneCIS Insurance Company of Lynn, MA have inspected the items described in this Owners Activity Report, and state that, to the best of my knowledge and belief, the Owner has performed all activities represented by this report in accordance with the requirements of Section XI.

By signing this certificate neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the repair/replacement activities and evaluation described in this report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this inspection.

Dustin Mallet Commissions 15196; AI, IS, I, N, R Inspectors Signature National Board, State, Province, and Endorsements Date 07/21/2021 SC 363 DBM0638 (125595) dc=eom, dc=duke-energy, dc=ent, dc=nam, ou=Accounts, ou=Personal, ou=PNTransitional, cn=DBM0638 (125595), email=Daniel.Mayes@duk~nergy.com 2021.07.2110:46:05-04'00'

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Catawba Nuclear Unit 2 Form OAR-1 Owners Activity Report Table 1 Items with Flaws or Relevant Conditions that Required Evaluation for Continued Service Examination Category and Item Number Item Description Evaluation Description Category B-Q B16.20 Steam Generator Tubing in U-Tube Design No ASME Section XI Acceptance Requirement Exceeded (Reference Attached Inspection Report)

Catawba Nuclear Unit 2 Form OAR-1 Owners Activity Report Table 2 Abstract of Repair/Replacement Activities Required for Continued Service Code Class Item Description Description of Work Date Completed Repair / Replacement Plan Number 1

Steam Generator 2B (2 NC HX B)

Plugged and stabilized 7 tubes via rolled plug and wire rope stabilizer 4/14/2021 20415442-05 1

Steam Generator 2C (2 NC HX C)

Plugged and stabilized 2 tubes via rolled plug and wire rope stabilizer 4/13/2021 20415443-05 1

Steam Generator 2D (2 NC HX D)

Plugged and stabilized 7 tubes via rolled plug and wire rope stabilizer 4/14/2021 20415445-05

Catawba 2 EOC24 Steam Generator Tube Inspection Report (reference Catawba technical Specification 5.6.8)

Summary of inspections and inspection results:

a) The scope of inspections performed on each SG follows:

Bobbin / Array Inspection 100% full length (except Row 1-6 U-bend region)

Row 1-6 hot leg (HL) and cold leg (CL) straight section Array Inspection 100% Row 1-6 U-bend Pre-planned Array Special Interest 100% of DNT at top TSP (08H, 09C +/-

Confirmed tubesheet array indications fr TSP indications sized with bobbin or array from Confirmed PLP from New high stress tubes New Array Special Interest Possible loose part (PLP) calls with a one tube box-in of target tube Two tube box-in of target tube of known foreign object location New wear indications All bobbin I-codes New dent calls Visual Inspection Previously installed plugs Bowl cladding (NSAL-

-1) inspection Area of missing stainless steel clad Tube slippage monitoring (based on bobbin results) tubesheet and preheater in all 4 steam Miscellaneous Tube slippage monitoring (based on bobbin results)

-like indication detected (aside from those exempted by H*)

b. Degradation mechanisms found Degradation found included wear at support structures, wear from foreign objects, and crack-like indications near the tube ends The inspection scope for all four steam generators was as 100% ofDNT?.2.0V 1.25 inch) om2EOC23 2EOC23 2EOC23 12 Entire channel head surface in 2DHL Foreign object search and retrieval (FOSAR) of the generators.

+POINT and/or Ghent probe on any crack

+POINT and/or Ghent probe on loose part TSP wear indications (as needed)

c. Non-destructive examination techniques utilized for each degradation mechanism The bobbin / array combo probe was utilized for the detection wear at support structures, and wear from foreign objects The array probe was used for detection of crack-like indications near the tube ends The bobbin probe was used to size wear at support The array probe was used to size the foreign object wear

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

Tubes with anti-vibration bar wear indications A - 84 tubes/1 9 indications B -

indications C - 49 tubes/74 indications D - 76 tubes/109 indications Total -

77 indications is Tubes with tube support plate wear indications A - tubes/ indications B - 1 tubes/1 indications C - 4 tubes/4 indications D - tubes/ indications Total -

ubes/

indications broached TSP wear-baffle plate (drilled) wear The maximum growth observed in single flaw for TSP wear Tubes with tube presumed foreign object wear indications A -

tubes/

indications B -

tubes/

indications C - 7 tubes/7 indications D - 11 tubes/

indications Total - 44 tubes/47 indications Tubes with crack like indications within the tubesheet at the tube end A - 18 tubes/19 indications B -

tubes/

indications C - 4 tubes/ 4 indications D - 41 tubes/46 indications Total -

6 tubes/ 11 indications structures.

The complete listing for service induced indications is attached (AVB)

SG2 5

SG 2 23 tubes/35 SG2 SG2 232 tubes/3 The 95th percentile growth rate for AVB wear

2. 05% TW/EFPY SG2 2

2 SG2 2

2 SG2 SG2 5

5 23 t 23 21 2

is 3.4% TW/EFPY.

SG2 12 12 SG2 24 25 SG2 SG2 13 SG2 SG2 213 222 SG2 2

2 SG2 29 3

e.

Number of tubes plugged during the inspection outage for each degradation mechanism B

There were seven (7 Six (6) were for new high stress tubes (1) tube was plugged due to wear from a foreign object that was still present The tubes plugged SG 2B Count Row Tube Reason 1

99 New High Stress Tube New High Stress Tube 4

64 New High Stress Tube 66 New High Stress Tube 6

98 New High Stress Tube 7

99 New High Stress Tube Steam C

There were two (

Both were The tubes plugged SG 2C Count Row Tube Reason 1

New High Stress Tube 6

97 New High Stress Tube D

There were seven (7) tube was plugged due to wear from a foreign object SG 2D Count Row Tube Reason 1

17 New High Stress Tube 44 78 New High Stress Tube 48 81 New High Stress Tube 4

49 New High Stress Tube 49 New High Stress Tube 6

49 76 New High Stress Tube 7

100 Steam Generator 2A:

There were no tubes to plug.

Steam Generator 2 :

) tubes plugged were as follows:

12 75 2

36 3

37 52 37 5

37 37 37 Generator 2 :

2) tubes plugged.

were as follows:

36 92 2

3 Steam Generator 2

. One FOwearat 3H for new high stress tubes.

tubes plugged Six (6) were for new high stress tubes. One (1)

The tubes plugged were as follows:

26 2

3 54 5

55 36 FO wear at AVE 3 at 43 %TW

f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator.

1 A

B C

D Total

- 4 88 77 108 407

- 4 0

7 7

16 Total 88 141 79 1

4

% Plugged 9

1= There are 4578 tubes per steam generator

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

The was and was was 1 and

- 4 was for

-1 All structural and leakage performance criteria were met for wear with more than adequate margin 6

broached TSP wear is sufficient to demonstrate a

-case depth for broached TSP wear observed depth of drilled TSP wear is sufficient to st-case depth for drilled TSP wear observed 11 foreign object wear is sufficient to

-case depth for foreign object wear observed No degradation was detected in the plug visual Bowl cladding inspections at did identify an area of missing stainless-steel D hot The area of missing stainless-steel cladding was inspected at

- 4 no changes were No in-Steam Generator 2

2 2

2 Prior to EOC 2 133 EOC2 2

15 23

1. 3 3.09 1.73 2.52 2.31 EFPYfor EOC 24 was 1.46 EFPY. The cumulative EFPYfor EOC 21 25.67 EOC 23 27.10 and EOC 23 28.5 EOC 2 29.97. The EFPY EOC was 0.92 Condition monitoring was met for all degradation.

An NDE maximum depth of55.5%TW or less for AVB wear is sufficient to demonstrate a minimum degraded tube burst pressure of 3L1P, 4392 psi, at 0.95 probability with 50%

co,ifidence. The worst case depth for A VB wear observed during the inspection was an NDE depth of 3 %TW.

An NDE maximum depth call of 50.1%TW or less for minimum degraded tube burst pressure of 3L1P, 4392 psi, at 0.95 probability with 50% co,ifidence. The worst during the inspection was an NDE 34%TW.

An NDE maximum depth call of 51.2%TW or less for demonstrate a minimum degraded tube burst pressure of 3L1P, 4392 psi, at 0.95 probability with 50% co,ifidence. The wor during the inspection was an NDE depth of %TW.

An NDE maximum depth call of 53%TW or less for demonstrate a minimum degraded tube burst pressure of 3L1P, 4392 psi, at 0.95 probability with 50% confidence. The worst during the inspection was an NDE depth of 43%TW.

EOC 21 cladding in the Catawba Unit 2 SG leg channel head EOC2 noted There was no degradation detected in any of the other bowl cladding inspections.

situ tests or tube pulls were performed.

object accumulation or where indicated by metallic objects were found in either the TTS or waterbox/preheater section Two objects were removed and the remaining six were evaluated for continued operation as is for three cycles i

A top of tubesheet sludge lancing was performed in all four steam generators during

h. For Unit 2, the primary to secondary LEAKAGE rate observed in each SG (if it is not practical to assign 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.

There was no primary to secondary leakage above detection limits during the preceding cycle 4

i.

For Unit 2, the calculated leakage rate from the portion of the tubes below 14.01 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident leakage rate from the most limiting accident is less than 3.27 times the maximum primary to secondary LEAKAGE rate, the report shall describe how it was determined.

from the top of the tubesheet, for the most lim

j.

For Unit 2, the results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.

No indications of slippage were detected Foreign, Object Search and Retrieval (FOSAR) was performed in areas of known foreign, eddy current examination. FOSAR was performed at the top of tube sheet and the waterbox/preheater section. Eight An upper bundle visual inspection was performed in the steam generator 2A, no degradation was detected The broached blockage was much improved over the previous nspection. No foreign, objects were found in either the upper bundle of the 2A SG.

EOC 24. There were 67 pounds removed from the A SG, 54.5 pounds removed from the B SG, 72 pounds removed from the C SG and 76 pounds removed from the DSG. The total deposits removed was 269.5 pounds.

A DMT was performed approximately 537 5 pounds of deposit were removed No other secondary side work was performed 2 operation.

There was no calculated leakage from the portion of the tubes more than 14.01 inches iting accident in the most limiting SG.

List of Service Induced Indications Catawba 2, EOC-24

SG - 2A Attachment 1 - Service Induced Indications Catawba Nuclear Station 2 2EOC24 DDP 20210401 05/18/2021 13:46:39

+----+----+---------+----+----+----+-----+----+---------+---------+---------+---------+-------+----+-------+----+----+------+------+------+--+-----+