ML13346A630

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Calculation M-93-038, Impact of Pipe Clamp on Calvert Cliffs Nuclear Power Plant Component Cooling Water Piping Stress
ML13346A630
Person / Time
Site: Calvert Cliffs Constellation icon.png
Issue date: 11/08/2013
From: Morgan M
Calvert Cliffs
To:
Office of Nuclear Reactor Regulation
References
ILD-CALC-0013, Rev 0, RR-ISI-04-09 M-93-038
Download: ML13346A630 (98)
v • d • e


Text

ENCLOSURE (6)

CALCULATION M-93-038 (25 pages)

Calvert Cliffs Nuclear Power Plant, LLC December 6, 2013

DESIGN ENGINEERING AND CONFIGURATION CNG-FES-015 MANAGEMENT FORMS Revision 00006 FORM 3, ENGINEERING CHANGE NOTICE (ECN)

Page I of I ECN No.: rCP-1l3-000947-TCN-03-CNw001 Rev. No.: 0000 INITIA'TION Parent Product ID: M p-93-038 Revision No. 01 Parent Product Type: calculation

Title:

Component Cooling Pu~mp Room Piping - Unit 2 Site (check on4): CCNPP '" NM P [3 REG E UNIT I ZUNIT 2 [- COMMON ED ISFSI Safely Classification I] SR IZ NSR ED Augmented Quality B, I)I.gCRIPTION OF CIiA(,NI-,;:

A PIPE CLAMP IS FIIrNG INSTALLED PER BC]'- 13-000947 Rlv. 0 TO SHAL, A THRU-WAI.L IEAK IN lIJ I PIPING AI" APPROXIMATIELY NODi 290 xkS SiHOWN ON DWG 91374 SFIET 1.

C. JUJSTIFICATION:

AN IVAI.UATIIN WAS PFRFOI:*NII'D IN ViNI)OF, DOCUMFNT ILD-CALC-0013 Rr:v. 0 (ITAc't:!o) T FOUND INSI'ALLATiON OF TIlE PIPE CLAMP ACCF!PT\I3I.E WITH REGARD TO PIP' SfTRE.SS, PIPE SUPPORT 1.OADS AND 1"1117 I)ISPI.ACEME!r"S, AND HEAT EXCHANGER NOZZLE LOADS.

USEI ADDITIONAL SHEETS AS REQUIRED Check if additional shects used [

[ Cancelled

[ [NMP Onlyl Change existing p usting Iro Document _ from "C" to "R" to avoid duplicate posting.

R ElVIE W AN1) APPROVAL:

., ; II .... *n~

Electronic Signature (Primed Nanweand Situture) Datc:

Is Design Verification Required? Z Yes F1 No If yes, Design Verification Form is DJ Attnched [] Filed with: ECP-13-000947 Rev. 0 Independent Reviewer: Michael Tompkins ___ (ILD, Inc1)

El Electronic Signature (Prinlcd Nanic and Signature) Datle:

L. ' . ..... .......

Approval:

.-0'tinted Name add Signamrcl

  • bate:

E] Electronic Signature

ILD Calculation Cover Sheet Date: 11/5/2013 Calculation No: ILD-CALC-0013 Revision No: 0 Impact of Pipe Clamp on Calvert Cliffs Nuclear Power Plant Component Calculation

Title:

Cooling Water Piping Stress Project Number: 1002-0040 Revision History: Include general descviplion as well as pages changed, added, superseded,or voided.

Rev 0: Initial Issue Calculation Type: [I Safety Related E] Non-Safety Related Design Verification Required?: El No E] Yes (See ILD-EP-0015)

IDV was performed in combination with IDV of CCNPP ECP-13-00947. See ECP-13-00947 for record of IDV.

Namne/Signature Required below.

Preparer: Michael Morgan.. Date:

Reviewer: Michael Tom pki nsf.. .- < Date: ,.///*'

Design Verifier: Bob Stakenborghs Date: k(s'i Approver: Lindsey Dziuba , Date: L Total Number of Pages 3,00.9 Page 1

ILD-CALC-0013 REV 0 Job #1002-0040

-/LD ILD-CALC-0013 REV 0 November 8, 2013 Impact of Pipe Clamp on Calvert Cliffs Nuclear Power Plant Component Cooling Water Piping Stress Table of Contents

1.0 Purpose and Scope

........................................................................................................................... 4 2 .0 D e sig n In p u t ...................................................................................................................................... 4 3 .0 A ssu m p tio n s ..................................................................................................................................... 5 4.0 Methodology and Acceptance Criteria ........................................................................................ 6 5.0 Documentation of Computer Code ............................................................................................. 9 6.0 Calculations and Results ....................................................................................................... 9 7 .0 C on clu sio n ...................................................................................................................................... 23 8 .0 Re fe re n ce s ...................................................................................................................................... 23 9 .0 Attach m e nts ................................................................................................................................... 24 List of Attachments Attachment A: M E101 Benchmark Input (ILD-CALC-0013_R0_BM.inp) ............................................ 7 pages Attachment B: M E101 Pipe Clamp Input (ILD-CALC-0013_ROCLAMP.inp) ...................................... 7 pages Attachment C: M E101 Pipe Separation Input (ILD-CALC-0013_RO S.inp) ......................................... 7 pages Attachment D: ME101 Benchmark Output (ILD-CALC-0013 _RO0BM.out) .................................... 981 pages Attachment E: ME101 Pipe Clamp Output (ILD-CALC-0013_ROCLAM P.out) ............................... 981 pages Page 2 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Attachment F: ME101 Pipe Separation Output (ILD-CALC-0013 R0 S.out) .............. 1001 pages Attachm ent G : CCNPP Correspondence ............................................................................................. 1 page Revision History Rev. 0 - Initial Issue, Page 3 of 24

ILD-CALC-0013 REV 0 Job #t1002-0040

1.0 Purpose and Scope

During the early-September 2013 forced Unit 2 shutdown a pin-hole leak was identified on the Calvert Cliffs Unit 2 Salt Water (SW) pipe line 12"-U1-2011. The SW pipe with the hole is connected to the discharge of Component Cooling Water (CCW) heat exchanger No. 21. In order to mitigate the adverse effects of the hole in the piping, a clamp is being installed to seal the pipe (Ref. 8.1).

This calculation will evaluate the impact of the clamp weight on the Component Cooling Water salt water piping stress, pipe support loads, and heat exchanger nozzle loads. Additionally, the loads on the piping and supports are evaluated for thrust loads that would occur in the event of a pipe separation at the location of the leak. This calculation does not evaluate the local stress on the piping due to the installation of pipe clamp. That evaluation will be completed in ILD-CALC-0014 (Ref. 8.4). ILD-CALC-0014 will use the piping forces and moments from this evaluation to determine the acceptability of the clamp design. This calculation is safety related.

2.0 Design Input 2.1 The model input for all existing piping and the applicable stress results are taken from CCNPP Calculation M-93-038 Rev. 1 (Ref. 8.2). A review of the outstanding calculation comments on M-93-038 Sheet 6 was completed, and it was verified that there is no impact on this analysis. Also, a review of existing calculation change notices against M-93-038 was performed. There is no impact on this calculation, In the thermal stress analysis (Eqn.

13/14) defined by TEA (thermal evaluation analysis control word) in the M-93-038 input, the load case SEISDB was not excluded. The thermal analysis shouldn't include seismic loads and therefore, has been excluded from the TEA input for correctness. Since this analysis does not change any thermal cases, there is no affect on the analysis.

2.2 The salt water cooling piping layout and node numbers are given on CCNPP Drawing 91374 Sheet 1 (Ref. 8.3) 2.3 The pipe clamp assembly weight is approximately 233.7 lbs per CCNPP Calculation CA08093 Rev. 0 (Ref. 8.1 Attachment E). Therefore, the use of 240 lbs in the ME101 model will be bounding.

2.4 The piping code of record for the CCW salt water piping is USAS B31.1 1967 (Ref. 8.5).

2.5 Pipe supports SK-42075 and SK-42076 have a minimum margin of 20% using loads 15%

greater than those given in M-93-038 per CCNPP Calculation CA00700 (Ref. 8.6) and CA00702 (Ref. 8.7). The design basis calculations for these supports are C-93-058 (Ref. 8.14) and C-93-059 (Ref. 8.15).

2.6 Pipe Support 5K-42073 has a minimum load ratio of 0,89 for the south-side base plate bolt interaction per CCNPP calculation C-93-056 (Ref. 8.16). The support was analyzed with a design load of +/-11,000 lbs in the x-direction, 1,500 lbs in the positive y-direction, and 4,710 lbs in the negative y-direction. The loads were qualified using faulted loads compared against normal load allowables. A review of the as-built modifications for this support (Ref.

8.17 through 8.20) was performed, and there is negligible affect on this analysis.

2.7 Per Ref. 8.1, the through-wall leak Is located on 12" diameter class U-1 piping. The operating pressure of U1 piping is 35 psig per Piping Class Summary Sheet M-601 (Ref. 8.9).

Page 4 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Per Piping Class Sheet M-600 (Ref. 8.10), the piping is standard weight. The internal area of standard 12" pipe is 0.7854 ftW per Crane Technical Paper No. 410 (Ref. 8.11) when using the nominal wall thickness.

2.8 Correspondence with CCNPP plant personnel indicates that the maximum flow rate through the salt water piping is 7,000 gpm (see Attachment G).

2.9 The maximum density of salt water of salt water is 64.1 Ibm/ft 3 per ASME PTC 12.2 Appendix I (Ref. 8.12). Using a larger density corresponding to a temperature less than typical operating temperatures is more conservative. The density assumes normal salinity of sea water (see Section 3.3).

3.0 Assumptions 3.1 The pipe clamp weight is added as a single mass to node point 290 (Ref. 8.3). Per Ref. 8.1, the installed clamp CG will be approximately 13 inches downstream of valve 2-CV-5206, Node 290 is 5 inches downstream of the centerline of the valve and between 0.5 and 1.5 inches downstream of the valve flange. The next closest node is node 286, which is 38 inches downstream of the valve centerline. Node 290 is sufficiently close to the actual clamp mounting location to approximate any stress induced on the piping by the installation of the pipe clamp. Additionally, since node 290 has an assigned SIF of 1.3 and the clamp is installed on a straight run of pipe (no additional SIF) the calculated stress is conservative at this location.

3.2 In order to model the event of a full circumferential pipe break, a two inch dummy element was added between Node 286 and 290 for the pipe separation model (Attachment C). This element was given a low stiffness (modulus of elasticity of 1 psi) to allow the ends of the piping created by the "break" to move independently. This dummy element has no impact on the pipe loads or movement. It only serves to connect the piping upstream of the break to the remaining piping of the model.

3.3 The salinity of the salt water in the piping is assumed to be of normal concentration. This is a reasonable assumption since CCNPP salt water is taken from the Chesapeake Bay and not a high-salinity source.

3.4 Only supports near the clamp are evaluated for this analysis since they will bear the vast majority of load induced on the system by the clamp and postulated break. The remaining pipe supports are deemed acceptable by judgment due to their relatively distant proximity.

  • Support SK-42076 Is nearest to the installation location of the clamp. This support's restraint direction is in the global Y-direction.
  • Support SK-42075 Is the nearest support with restraint in the global Z-direction. It also provides support in the global Y-direction.
  • Support SK-42073 is the nearest support with restraint in the global X-direction. It also provides support in the global Y-direction.

Page S of 24

ILD-CALC-0013 REV 0 Job #1002-0040 4.0 Methodology and Acceptance Criteria CCNPP Calculation M-93-038 Rev. I (Ref. 8.2) is the calculation of record for the Unit 2 CCW system salt water piping. M-93-038 uses the Bechtel-developed software ME101 (see Section 5.0) to calculate the code stresses and support loads in accordance with the CCNPP code of record for this piping, USAS 831.1 1967 (see Section 2.4).

4.1 Benchmark Calculation M-93-038 only gives the maximum computed stresses in the salt water piping.

Therefore, the exact input used previously will be rerun to determine the loads and stresses at node 290 for comparison purposes. The benchmark ME101 input file (ILD-CALC-0013 RO BM.inp) is in Attachment A.

4.2 Pipe Clamp Installation In order to evaluate the impact that the added weight of the pipe clamp has on the piping system, a weight of 240 lbs is added to node 290 (Assumption 3.1 and Design Input 2.3). No other changes are made to the model. The results are compared against those in the benchmark model to determine how the clamp affects pipe stresses and support loads. The ME101 input file (ILD-CALC-0013 ROCLAMP.inp) for the pipe clamp installation is in Attachment B.

4.3 Pipe Separation A third model was developed to postulate pipe movements should the salt water piping have a circumferential break at node.290. In order to do this, a dummy element with low stiffness was added in between Nodes 286 and 290 (see Section 3.2). On each end of the dummy element, an axial thrust load is imposed to account for loads induced by the salt water flowing from the break. The ME101 input file for the pipe separation case is in Attachment C (ILD-CALC-0013_ROS.inp).

The two axial thrust loads are oriented in the model such that their actions serve to push the piping apart at the break, simulating the thrust of salt water leaving the system in the event of a break. Per Ref. 8.8, the thrust load due to the blowdown of a fluid jet can be calculated from the conservation of momentum as follows:

T = 144(AE)(Po - P.) + pV 2 AE Equation 1 Where: T = Thrust Load (Ibs)

AE = Area of the Pipe Opening (ft2)

P, = Stagnation Pressure of the Liquid (psi)

Pý = Atmospheric Pressure (psi)

Page 6 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 p = Density of the Fluid (Ibm/ft3 )

V = Velocity of the Fluid (ft/sec) 4.4 Acceptance Criteria 4.4.1 Pipe Stress The results of the analysis are considered acceptable if the calculated pipe stress is less than the given allowable. The pipe stress allowables for A53 Gr B Welded (material for node 290) and A377 GR 30 are as follows:

Table 4 USAS 831.1 1967 Allowable Stresses (A53 GR BWelded)

ALLOWABLE STRESS DESIGN (PSI)

CONDITION LEVEL SUSTAINED LOADS 1.0 x SH 12,700 EQN. 11 OCCASIONAL LOADS B 1.2 x SH 15,240 EQN. 12 OCCASIONAL LOADS D 2.4 x SH 30,480 EQN. 12 THERMAL EXPANSION 1.0 x SA 19,050 EQN. 13 Page 7 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 4 USAS B31.1 1967 Allowable Stresses (A377 GR 30)

DESIGN DESPSI) ALLOWABLE STRESS LEVEL CONDITION SUSTAINED LOADS 1.0 x SH 3,000 EQN. 11 OCCASIONAL LOADS B 1.2 x SH 3,600 EQN. 12 OCCASIONAL LOADS D 2.4 x SH 4,800" EQN. 12 THERMAL EXPANSION 1.0 x SA 19,050 EQN. 13

  • Per M-93-038 page 13 Note 2, Sy for Gray Cast Iron Gr. 30 is not available, so pipe stresses are compared with SH/0.625 = 4,800 psi.

4.4.2 Pipe Supports Per Refs. 8.6 and 8.7, the nearest pipe supports (SK-42076 and SK-42075) have a minimum of 20% margin when using loads 15% greater than given in Ref. 8.2 (see Section 2.5). Therefore, if the loads due to the added weight of the clamp system increase less than 20%, then they will be acceptable by inspection. If the load increases are greater, the supports will need to be evaluated in more detail. If the two closest supports' load increases are acceptable, then the supports further away are deemed acceptable by judgment (Assumption 3.4).

The closest support that restrains the piping in the X-direction is SK-42073. The components with the least margin in support SK-42073 are the South-side base plate bolts. Their maximum interaction ratio is 0.89 (ratio of tension to allowable plus ratio of shear to allowable). The load ratios for all other components in the support are much less. The maximum design load for this support is +/-11,000 lbs in the x-direction, 1,500 lbs in the positive y-direction, and 4,710 lbs in the negative y-direction (Ref. 8.16). If the load increases are bound by the maximum analyzed design loads, then the results are acceptable.

4.4.3 Heat Exchanger Nozzle The CCW Heat Exchanger nozzle loads were evaluated in M-93-038 Attachment 11 and 14. Since it has been shown that the nozzle loads are acceptable at those levels, Page 8 of 24

ILD-CALC-0013 REV 0 Job # 1002-0040 if the results of this analysis give loads less than the previously evaluated loads, then the nozzle is acceptable.

Table 4 CCW Heat Exchanger 21 Outlet Nozzle Loads at Node 350 (Ref. 8.2 Attachment 14 Page 2)

Load Force (Ibs) Moment (ft-lbs)

Case Fx Fy Fz Mx My Mz Norm 11,161 3,711 3,096 9,003 11,964 30,500 Upset 12,643 4,102 3,620 10,306 12,671 34,609 Faulted 13,731 4,429 6,785 18,886 24,510 37,625 5.0 Documentation of Computer Code This calculation uses the computer software ME101 version N9 developed by Bechtel to analyze piping structures. The software input was developed at ILD's Baton Rouge offices and run on CCNPP's computers. CCNPP maintains ME101 as safety related under their Quality Assurance Program. ME101 was validated under CCNPP calculation CA04657 Rev. 6 (Ref. 8.13). The program input and output are as specified in Sections 4.0 and 6.0. The output files contain the date the input file was run, and therefore, that date applies to the corresponding input file as well. The models were run on CCNPP computer station PCG7147 in accordance with Ref. 8.13.

6.0 Calculations and Results 6.1 Benchmark The ME101 model output for the benchmark evaluation is in Attachment D (ILD-CALC-0013_ROBM.out). The reported maximum stresses are the same as given in M-93-038 (stresses for node 135 were not given in M-93-038 but are listed here for completeness),

repeated in Table 6-1 below.

Page 9 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 Maximum Pipe Stress (Benchmark)

LOCATION MAXIMUM ALLOWABLE COMPUTED DESIGN OF MAXIMUM COMPUTED STRESS CONDITION LEVEL END ELEMENT STRESS(PSI) (PSI) ALLOWABLE SUSTAINED SH LOADS 440 435 M EON.S 440 1,263 3,000 0.421

-EQN. 11 440 SUSTAINED SH LOADS 135 135 4,752 12,700 0.374 EQN. 11 140 OCCASIONAL 1.2 SH LOADS B 440 435 M 2,843 3,600 0.790 EQN. 12 440 OCCASIONAL 1.2 SH LOADS B 135 135 6,341 15,240 0.416 EQN. 12 140 OCCASIONAL 2.4 SH LOADS D 440 435 M 4,193 4,800 0.874 EQN. 12 440 OCCASIONAL 2.4 SH LOADS 0 135 135 7,642 30,480 0.251 EQN, 12 140 THERMAL SA EXPANSION 180 180 17,239 19,050 0.905 EQN. 13 197 Two additional nodes are of interest for the installation of the pipe clamp. The benchmark stresses at node 290 (the location of the clamp installation) and node 395 (the nearest non-heat exchanger pipe anchor) are given below.

Page 10 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 Pipe Stress at Node 290 (Benchmark)

LOCATION MAXIMUM ALLOWABLE COMPUTED DESIGN OF MAXIMUM COMPUTED STRESS CONDITION LEVEL END ELEMENT STRESS(PSI) (PSI) ALLOWABLE SUSTAINED SH LOADS 290 286 1,141 12,700 0.090 EQN. 11 290 OCCASIONAL 1.2 SH LOADS B 290 286 1,463 15,240 0.096 EQN. 12 290 OCCASIONAL 2.4 SH LOADS D 290 286 1,704 30,480 0.056 EQN. 12 290 THERMAL SA EXPANSION 290 286 5,635 19,050 0.296 EQN. 13 290 Table 6 Pipe Stress at Node 395 (Benchmark)

LOCATION MAXIMUM ALLOWABLE COMPUTED DESIGN OF MAXIMUM COMPUTED STRESS CONDITION LEVEL END ELEMENT STRESS(PSI) (PSI) ALLOWABLE SUSTAINED SH LOADS 395 390 1,031 12,700 0.081 EQN. 11 395 OCCASIONAL 1.2 SH LOADS B 395 390 1,711 15,240 0.112 EQN. 12 395 OCCASIONAL 2.4 SH LOADS D 395 390 2,211 30,480 0.073 EQN. 12 395 THERMAL SA EXPANSION 395 390 4,991 19,050 0.262 EQN. 13 395 The two nearest pipe supports are SK-42076 and SK-42075. The benchmark loads for these supports are as follows. The loads and displacements exclusively due to the postulated thermal cases are not repeated here since there is no effect on those analyses.

Page 11 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 Benchmark SK-42075 Loads and Displacements (Y-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 -5,758 0 -5,758 0.000 0.000 0.000 0.000 SEISOB 0 822 0 822 0.000 0.000 0.000 0.000 SEISBD 0 1,540 0 1,540 0.001 0.000 0.000 0.000 MAXNRM 0 -4,467 0 -4,467 0.023 0.000 0.000 0.000 MINNRM 0 -7,562 0 -7,562 -0.035 0.000 0.000 0.000 MAXUPS 0 -3,645 0 -3,645 0.023 0.000 0.000 0.000 MINUPS 0 -8,384 0 -8,384 -0.035 0.000 0.000 0.000 MAXFLT 0 -2,903 0 -2,903 0.023 0.000 0.000 0.000 MINFLT 0 -9,940 0 -9,940 -0.045 0.000 0.000 0.000 Table 6 Benchmark SK-42075 Loads and Displacements (Z-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 0 143 143 0.000 0.000 0.000 0.000 SEISOB 0 0 1,871 1,871 0.000 0.000 0.000 0.000 SEISBD 0 0 3,245 3,245 0.001 0.000 0.000 0.000 MAXNRM 0 0 7,358 7,358 0.023 0.000 0.000 0.000 MINNRM 0 0 -5,711 -5,711 -0.035 0.000 0.000 0.000 MAXUPS 0 0 9,229 9,229 0.023 0.000 0.000 0.000 MINUPS 0 0 -7,582 -7,582 -0.035 0.000 0.000 0.000 MAXFLT 0 0 10,603 10,603 0.023 0.000 0.000 0.000 MINFLT 0 0 -8,956 -8,956 -0.045 0.000 0.000 0.000 Table 6 Benchmark SK-42076 Loads and Displacements Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX i DY DZ DA WTOP 0 -7,522 0 -7,522 -0.004 0.000 0.003 0.000 SEISOB 0 1,109 0 1,109 0.007 0.000 0.006 0.000 SEISBD 0 2,069 0 2,069 0.012 0.000 0.011 0.000 MAXNRM 0 -5,736 0 -5,736 0.024 0,000 0.018 0.000 MINNRM 0 -8,674 0 -8,674 -0.047 0.000 -0.027 0.000 MAXUPS 0 -4,628 0 -4,628 0.031 0.000 0.024 0.000 MINUPS 0 -9,783 0 -9,783 -0.054 0.000 -0.033 0.000 MAXFLT 0 -2,972 0 -2,972 0.036 0.000 0.039 0.000 MINFLT 0 -11,006 0 -11,006 -0.078 0.000 -0.038 0.000 Page 12 of 24

ILD-CALC-0013 REV 0 Job #l1002-0040 Table 6 Benchmark SK-42073 Loads and Displacements (X-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP -366 0 0 -366 0.000 0.000 -0.001 0.000 SEISOB 1,579 0 0 1,579 0.000 0.000 0.001 0.000 SEISBD 2,738 0 0 2,738 0.000 0.000 0.001 0.000 MAXNRM 5,277 0 0 5,277 0.000 0.000 0.041 0.000 MINNRM -7,470 0 0 -7,470 0.000 0.000 -0.064 0.000 MAXUPS 6,856 0 0 6,856 0.000 0.000 0.041 0.000 MINUPS -9,049 0 0 -9,049 0.000 0.000 -0.065 0.000 MAXFLT 8,825 0 0 8,825 0.000 0.000 0.050 0.000 MINFLT -10,208 0 0 -10,208 0.000 0.000 -0.143 0.000 Table 6 Benchmark SK-42073 Loads and Displacements (Y-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 -2,068 0 -2,068 0.000 0.000 -0.001 0.000 SEISOB 0 326 0 326 0.000 0.000 0.001 0.000 SEISBD 0 605 0 605 0.000 0.000 0.001 0.000 MAXNRM 0 -562 0 -562 0.000 0.000 0.041 0.000 MINNRM 0 -2,995 0 -2,995 0.000 0.000 -0.064 0.000 MAXUPS 0 -235 0 -235 0.000 0.000 0.041 0.000 MINUPS 0 -3,321 0 -3,321 0.000 0.000 -0.065 0.000 MAXFLT 0 926 0 926 0.000 0.000 0.050 0.000 MINFLT 0 -3,600 0 -3,600 0.000 0.000 -0.143 0.000 6.2 Pipe Clamp Installation The ME101 model output for the evaluation of the effect of the pipe clamp system weight is in Attachment E (ILD-CALC-0013_ROCLAMP.out). Table 6-9 summarizes the comparison of the maximum pipe stresses that include the clamp weight to the piping allowables.

Page 13 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 Maximum Pipe Stress (Pipe Clamp Installed)

LOCATION MAXIMUM ALLOWABLE COMPUTED DESIGN OF MAXIMUM COMPUTED STRESS ---------

CONDITION LEVEL END ELEMENT STRESS(PSI) (PSI) ALLOWABLE SUSTAINED SH LOADS 440 435 M 1,263 3,000 0.421 EQN. 11 440 SUSTAINED SH LOADS 135 135 4,752 12,700 0.374 EQN. 11 140 OCCASIONAL 1.2 SH LOADS B 440 435 M 2,838 3,600 0.788 EQN. 12 440 OCCASIONAL 1.2 SH LOADS B 135 135 6,313 15,240 0.414 EQN. 12 140 OCCASIONAL 2.4 SH LOADS D 440 435 M 4,186 4,800 0.872 EQN. 12 440 OCCASIONAL 2.4 SH LOADS D 135 135 7,596 30,480 0.249 EQN. 12 140 THERMAL SA EXPANSION 180 180 17,239 19,050 0.905 EQN. 13 197 The maximum pipe stresses have negligible change due to the addition of the pipe clamp. The stresses at node 290 are given below.

Page 14 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 Pipe Stress at Node 290 (Pipe Clamp)

LOCATION MAXIMUM ALLOWABLE COMPUTED DESIGN OF MAXIMUM COMPUTED STRESS CONDITION LEVEL END ELEMENT STRESS(PSI) (PSI) ALLOWABLE SUSTAINED SH LOADS 290 286 1,279 12,700 0.101 EQN. 11 290 OCCASIONAL 1.2 SH LOADS B 290 286 1,625 15,240 0.107 EQN. 12 290 OCCASIONAL 2.4 SH LOADS D 290 286 1,887 30,480 0,062 EQN. 12 290 THERMAL SA EXPANSION 290 286 5,635 19,050 0.296 EQN. 13 290 Table 6 Pipe Stress at Node 395 (Pipe Clamp)

LOCATION MAXIMUM ALLOWABLE COMPUTED DESIGN OF MAXIMUM COMPUTED STRESS --...---

CONDITION LEVEL END ELEMENT STRESS(PSI) (PSI) ALLOWABLE SUSTAINED SH LOADS 395 390 1,036 12,700 0.082 EQN. 11 395 OCCASIONAL 1.2 SH LOADS B 395 390 1,722 15,240 0.113 EQN. 12 395 OCCASIONAL 2.4 SH LOADS D 395 390 2,227 30,480 0.073 EQN. 12 395 THERMAL SA EXPANSION 395 390 4,991 19,050 0.262 EON. 13 395 The sustained and occasional pipe stresses have increased by approximately 10%, but all pipe stresses due to the addition of the pipe clamp remain well within allowables.

The following tables give the pipe support loads due to the addition of the pipe clamp system.

Page 15 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 SK-42075 Loads and Displacements with Pipe Clamp Installed (Y-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 -5,829 0 -5,829 0.000 0.000 0.000 0.000 SEISOB 0 832 0 832 0.000 0.000 0.000 0.000 SEISBD 0 1,559 0 1,559 0.001 0.000 0.000 0.000 MAXNRM 0 -4,538 0 -4,538 0.023 0.000 0.000 0.000 MINNRM 0 -7,633 0 -7,633 -0.035 0.000 0.000 0.000 MAXUPS 0 -3,706 0 -3,706 0.023 0.000 0.000 0.000 MINUPS 0 -8,465 0 -8,465 -0.035 0.000 0.000 0.000 MAXFLT 0 -2,955 0 -2,955 0.023 0.000 0.000 0.000 MINFLT 0 -10,030 0 -10,030 -0.045 0.000 0.000 0.000 Table 6 SK-42075 Loads and Displacements with Pipe Clamp Installed (Z-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 0 130 130 0.000 0.000 0.000 0.000 SEISOB 0 0 1,890 1,890 0.000 0.000 0.000 0.000 SEISBD 0 0 3,277 3,277 0,001 0.000 0,000 0.000 MAXNRM 0 0 7,345 7,345 0.023 0.000 0.000 0.000 MINNRM 0 0 -5,723 -5,723 -0.035 0.000 0.000 0.000 MAXUPS 0 0 9,235 9,235 0.023 0.000 0.000 0.000 MINUPS 0 0 -7,613 -7,613 -0.035 0.000 0.000 0.000 MAXFLT 0 0 10,622 10,622 0.023 0.000 0.000 0.000 MINFLT 0 0 -9,000 -9,000 -0.045 0.000 0.000 0.000 Table 6 SK-42076 Loads and Displacements with Pipe Clamp Installed Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 -7,649 0 -7,649 -0.004 0.000 0.003 0.000 SEISOB 0 1,127 0 1,127 0.007 0.000 0.006 0.000 SEISBD 0 2,103 0 2,103 0.012 0.000 0.011 0.000 MAXNRM 0 -5,864 0 -5,864 0.024 0.000 0.018 0.000 MINNRM 0 -8,801 0 -8,801 -0.047 0.000 -0.027 0.000 MAXUPS 0 -4,736 0 -4,736 0.031 0.000 0.024 0.000 MINUPS 0 -9,928 0 -9,928 -0.054 0.000 -0.033 0.000 MAXFLT 0 -3,064 0 -3,064 0.036 0.000 0.039 0.000 MINFLT 0 -11,168 0 -11,168 -0.078 0.000 -0.038 0.000 Page 16 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 SK-42073 Loads and Displacements with Pipe Clamp Installed (X-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA VVTOP -402 0 0 -402 0.000 0.000 -0.001 0.000 SEISOB 1,593 0 0 1,593 0.000 0.000 0.001 0.000 SEISBD 2,763 0 0 2,763 0.000 0.000 0.001 0.000 MAXNRM 5,241 0 0 5,241 0.000 0.000 0.041 0.000 MINNRM -7,506 0 0 -7,506 0.000 0.000 -0.064 0.000 MAXUPS 6,834 0 0 6,834 0.000 0.000 0.041 0.000 MINUPS -9,100 0 0 -9,100 0.000 0.000 -0.065 0.000 MAXFLT 8,813 0 0 8,813 0.000 0.000 0.050 0.000 MINFLT -10,269 0 0 -10,269 0.000 0.000 -0.143 0.000 Table 6 SK-42073 Loads and Displacements with Pipe Clamp Installed (Y-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 -2,044 0 -2,044 0.000 0.000 -0.001 0.000 SEISOB 0 323 0 323 0.000 0.000 0.001 0.000 SEISBD 0 599 0 599 0.000 0.000 0.001 0.000 MAXNRM 0 -538 0 -538 0.000 0.000 0.041 0.000 MINNRM 0 -2,971 0 -2,971 0.000 0.000 -0.064 0.000 MAXUPS 0 -215 0 -215 0.000 0.000 0.041 0.000 MINUPS 0 -3,294 0 -3,294 0.000 0.000 -0.065 0.000 MAXFLT 0 944 0 944 0.000 0.000 0.050 0.000 MINFLT 0 -3,570 0 -3,570 0.000 0.000 -0.143 0.000 There is negligible difference in displacement due to the pipe clamp system. Additionally, the load increases are less than 20% for SK-42075 and SK-42076. The load increases for support SK-42073 remain within the maximum analyzed design load. Per Section 4.4, these loads are acceptable.

The HX 21 outlet nozzle loads (absolute value) for the piping with the clamp installed are given in Table 6-17. All loads are less than the originally analyzed loads in Table 4-3.

Table 6 CCW Heat Exchanger Outlet Nozzle Loads at Node 350 (Clamp Installed)

Load Force (Ibs) Moment (ft-lbs)

Case Fx Fy Fz Mx My Mz Norm 9,766 3,300 2,684 7,832 10,138 26,556 Upset 11,078 3,651 3,152 9,002 11,015 30,198 Faulted 12,042 3,945 5,914 16,487 21,338 32,872 Page 17 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 6.3 Pipe Separation The thrust load to be applied at each end of the dummy member is calculated using Equation 1:

T = 144(AE)(Po - P"') +POV 2 AE The pipe's fluid velocity is calculated from the volumetric flow rate and internal pipe area (Design Input 2.7 and 2.8).

3 V _Q (7000gal/mrin)(O.1337ft /gal)(1min/60sec) - 19.86ft/sec Equation 2 2

AE (0,7854ft )

Where: Q = Volumetric Flow Rate (gal/min)

The thrust load is therefore:

T = 1 44(0.7854ft 2 ) (35ps) + (64.llbM/ft 3 )(19.86ft/sec) 2 (O'7854ft 2 )

32 .2 lb'-ft = 4,575 lbf 322lbf-.svc 2 Therefore, using 4,600 lbf of thrust on each end of the dummy member conservatively bounds deviations from the input (larger internal pipe diameter, etc.). Note that this thrust is conservative because it is the steady state thrust load that would be developed if the piping separated and steady state flow were allowed to develop from the open end. Since the ends will be encapsulated by the seal, steady state flow could not develop from the pipe ends (and spray outward).

The ME101 model output for the evaluation of the effect of pipe separation is in Attachment F (ILD-CALC-0013_RO0S.out). Table 6-18 summarizes the comparison of the maximum pipe stresses due to pipe separation at node 290 to the piping allowables.

Page 18 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 Maximum Pipe Stress (Pipe Separation)

LOCATION MAXIMUM ALLOWABLE COMPUTED DESIGN OF MAXIMUM COMPUTED STRESS ---------

CONDITION LEVEL END ELEMENT STRESS(PSI) (PSI) ALLOWABLE SUSTAINED SH LOADS 440 435 M 1,263 3,000 0.421 EQN. 11 44D SUSTAINED SH LOADS 335 M 335 B 5,968 12,700 0.470 EQN. 11 335 M OCCASIONAL 1.2 SH LOADS B 440 435M 2,839 3,600 0.789 EQN. 12 440 OCCASIONAL 1.2 SH LOADS B 335 M 335 B 7,579 15,240 0.497 EQN. 12 335 M OCCASIONAL 2.4 SH LOADS D 440 435 M 4,187 4,800 0.872 EQN. 12 440 OCCASIONAL 2.4 SH LOADS D 335 M 335 B 8,865 30,480 0.291 EQN. 12 335 M THERMAL SA EXPANSION 180 180 17,707 19,050 0.930 EON. 13 197 The maximum pipe stresses increase due to the separation of the piping due to increased displacements. Additionally, node 335M replaced node 135 as the highest stress node with SH equal to 12,700 psi. However, all stresses remain below allowables and therefore acceptable. Since the nodes near the break are free moving, there are negligible stresses at those locations. The pipe stress for node 395 is as follows.

Page 19 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 Pipe Stress at Node 395 (Pipe Separation)

LOCATION MAXIMUM ALLOWABLE COMPUTED DESIGN OF MAXIMUM COMPUTED STRESS ---------

CONDITION LEVEL END ELEMENT STRESS(PSI) (PSI) ALLOWABLE SUSTAINED SH LOADS 395 390 1,581 12,700 0.124 EQN. 11 395 OCCASIONAL 1.2 SH LOADS B 395 390 2,335 15,240 0.153 EQN. 12 395 OCCASIONAL 2.4 SH LOADS D 395 390 2,889 30,480 0.095 EQN. 12 395 THERMAL SA EXPANSION 395 390 3,100 19,050 0.163 EQN. 13 395 The following tables give the pipe support loads due to pipe separation.

Table 6 SK-42075 Loads and Displacements with Pipe Separation (Y-Dir)

Load Force (Ibs) I Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 -5,298 0 -5,298 -0.001 0.000 0.000 0.000 SEISOB 0 773 0 773 0.000 0.000 0.000 0.000 SEISBD 0 1,447 0 1,447 0.001 0.000 0.000 0.000 MAXNRM 0 -4,422 0 -4,422 0.022 0.000 0.000 0.000 MINNRM 0 -6,415 0 -6,415 -0.039 0.000 0.000 0.000 MAXUPS 0 -3,648 0 -3,648 0.022 0.000 0.000 0.000 MINUPS 0 -7,188 0 -7,188 -0.039 0.000 0.000 0.000 MAXFLT 0 -2,859 0 -2,859 0.022 0.000 0.000 0.000 MINFLT 0 -8,337 0 -8,337 -0.049 0.000 0.000 0.000 Page 20.of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 SK-42075 Loads and Displacements with Pipe Separation (Z-Dir)

Load Force (Ibs) ....... Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 0 -935 -935 -0.001 0.000 0.000 0.000 SEISOB 0 0 1,781 1,781 0.000 0.000 0.000 0.000 SEISBD 0 0 3,089 3,089 0.001 0.000 0.000 0.000 MAXNRM 0 0 4,929 4,929 0.022 0.000 0.000 0.000 MINNRM 0 0 -5,364 -5,364 -0.039 0.000 0.000 0.000 MAXUPS 0 0 6,710 6,710 0.022 0.000 0.000 0.000 MINUPS 0 0 -7,145 -7,145 -0.039 0.000 0.000 0.000 MAXFLT 0 0 8,018 8,018 0.022 0.000 0.000 0.000 MINFLT 0 0 -8,624 -8,624 -0.049 0.000 0.000 0.000 Table 6 SK-42076 Loads and Displacements with Pipe Separation Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 -7,048 0 -7,048 -0.030 0.000 0.009 0.000 SEISOB 0 994 0 994 0.013 0.000 0.006 0.000 SEISBD 0 1,855 0 1,855 0.022 0.000 0.011 0.000 MAXNRM 0 -5,908 0 -5,908 -0.023 0.000 0.045 0.000 MINNRM 0 -8,287 0 -8,287 -0.114 0.000 -0.009 0.000 MAXUPS 0 -4,914 0 -4,914 -0.010 0.000 0.052 0.000 MINUPS 0 -9,281 0 -9,281 -0.127 0.000 -0.015 0.000 MAXFLT 0 -3,695 0 -3,695 -0.001 0.000 0.072 0.000 MINFLT 0 -10,400 0 -10,400 -0.150 0.000 -0.031 0.000 Table 6 SK-42073 Loads and Displacements with Pipe Separation (X-Dir)

Load Force (Ibs) Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP -3,739 0 0 -3,739 0.000 0.000 0.000 0.000 SEISOB 2,114 0 0 2,114 0.000 0.000 0.001 0.000 SEISBD 3,667 0 0 3,667 0.000 0.000 0.001 0.000 MAXNRM -3,739 0 0 -3,739 0.000 0.000 0.041 0.000 MINNRM -9,040 0 0 -9,040 0.000 0.000 -0.068 0.000 MAXUPS -1,624 0 0 -1,624 0.000 0.000 0.042 0.000 MINUPS -11,155 0 0 -11,155 0.000 0.000 -0.069 0.000 MAXFLT -72 0 0 -72 0.000 0.000 0.055 0.000 MINFLT [ -12,707 0 0 -12,707 0.000 0.000 -0.148 0.000 Page 21 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 SK-42073 Loads and Displacements with Pipe Separation (Y-Dir)

Load Force (Ibs) _ Displacement (in)

Case FX FY FZ FA DX DY DZ DA WTOP 0 -2,165 0 -2,165 0.000 0.000 0,000 0.000 SEISOB 0 346 0 346 0.000 0.000 0.001 0.000 SEISBD 0 641 0 641 0.000 0.000 0.001 0.000 MAXNRM 0 -857 0 -857 0.000 0.000 0.041 0.000 MINNRM 0 -2,947 0 -2,947 0.000 0.000 -0.068 0.000 MAXUPS 0 -511 0 -511 0.000 0.000 0.042 0.000 MINUPS 0 -3,293 0 -3,293 0.000 0.000 -0.069 0.000 MAXFLT 0 568 0 568 0.000 0.000 0.055 0.000 MINFLT 0 -3,588 0 -3,588 0.000 0.000 -0.148 0.000 There is negligible difference in displacement due to pipe separation for supports SK-42075 and SK-42073. The movements for SK-42076 increased more significantly. A review of Ref.

8.15 indicates that the design of this pipe support allows free movement in the pipe's axial direction (Global Z). Additionally, there is a 0.5 inch gap on either side of the pipe in the Global X-direction. Since all displacements in the X-direction are less than 0.5", these movements are acceptable.

With the exception of the loads for SK-42073 and the Maximum Faulted load for SK-42076, the load increases are less than 20%. In the case of the Maximum Faulted load for SK-42076, the load is negative and less than the Minimum Faulted load, and therefore bounded by the acceptance criteria. Per Section 4.4, these loads are acceptable.

For support SK-42073, the loads in the y-direction remain within previously analyzed values and are acceptable. The maximum x-direction load is -12,707 lbs which is greater than the previous maximum analyzed load of 11,000 lbs. Increasing the bolt interaction load ratio (Design Input 2.6) by the ratio of load increase to design load:

(-12,707)/(-11,000)*0.89 = 1.028 > 1.0 However per Ref. 8.16, the support was analyzed using faulted loads compared against normal load allowables. Additionally, conservatisms exist in both this analysis and the original support analysis. If the faulted allowables were used and conservatisms removed, the bolts are acceptable by inspection.

The HX 21 outlet nozzle loads (absolute value) for the piping with the clamp installed are given in Table 6-25. All loads are less than the originally analyzed loads in Table 4-3.

Page 22 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 Table 6 CCW Heat Exchanger Outlet Nozzle Loads at Node 350 (Pipe Separation)

Load Force (ibs) Moment (ft-ibs)

Case Fx Fy Fz Mx My Mz Norm 9,200 2,984 0 371 2 24,469 Upset 9,716 3,410 516 1,964 2,072 26,879 Faulted 10,095 3,783 895 3,133 3,513 28,977 The magnitude of pipe separation in the event of a circumferential break is calculated from the resultant displacement between nodes 287 and 288 under normal sustained load conditions. The resultant movement is approximately 9/64" and will be easily encapsulated by the length of the clamp.

Table 6 Resultant Pipe Movement Due to Circumferential Break Displacement (in)

Node DX DY DZ Resultant 287 -0,024 0.000 0.000 0.134 288 -0.004 -0.132 -0.003 7.0 Conclusion This evaluation determined the acceptability of installing a pipe clamp around a through wall leak in CCNPP Unit 2 CCW salt water piping with regard to pipe stress, pipe support loads, and nozzle loads.

All pipe stresses are within allowables. Pipe support load increases are bounded by the existing margin. Nozzle loads due to pipe separation and clamp installation are less than the loads originally used to qualify the nozzles. Additionally, the pipe clamp is large enough to entirely encapsulate the piping movement in the event of a full circumferential break in the piping at the location of the leak.

Therefore, there is no adverse impact due to the clamp installation on the piping system.

8.0 References 8.1 ECP-13-000947 Rev. 0 8.2 CCNPP Calculation M-93-038 Rev. 1, "Component Cooling Pump Room Piping - Unit 2" 8.3 CCNPP Drawing 91374 Sheet 1 Rev. 18, "Component Cooling Water Pump Room Piping -

Salt Water Cooling System - Unit 2" 8.4 ILD-CALC-0014 Rev. 0, "Evaluation of 12-U-1-2001 Line Enclosure" 8.5 Calvert Cliffs Engineering Standard ES-040 Rev. 00, "Piping Design Criteria" 8.6 CCNPP Calculation CA00700 Rev. 0, "Modification to Pipe Supports Associated with Salt Water Piping System" Page 23 of 24

ILD-CALC-0013 REV 0 Job #1002-0040 8.7 CCNPP Calculation CA00702 Rev. 0, "Evaluation of Pipe Supports for Salt Water Piping System due to Minor Deviation from Design Condition and/or Proximity to Adjacent Anchor Bolts" 8.8 Moody, F.J.; "Prediction of Blowdown Thrust and Jet Forces;" ASME 1969 8.9 Calvert Cliffs M-601 Piping Class Summary Sheets Rev. 49 8.10 Calvert Cliffs M-600 Piping Class Sheets Rev. 76 8.11 Crane Technical Paper No. 410, "Flow of Fluids Through Valves, Fittings, and Pipe,"

Reprinted 2006 8.12 ASME PTC 12.2-2010, "Steam Surface Condensers" 8.13 CCNPP Calculation CA04657 Rev. 6, "Accepts Version N9 on Individual LAN computers PCG3004, PCG7147, PCG8521, and PCH0730" 8.14 CCNPP Calculation C-93-058 Rev. 0, "Pipe Support Evaluation for SW Cooling System in the Component Cooling Pump Room" 8.15 CCNPP Calculation C-93-059 Rev. 0, "Pipe Support Evaluation for SW System in the Component Cooling Pump Room" 8.16 CCNPP Calculation C-93-056 Rev. 0, "Pipe Support Evaluation for SW Cooling System in the Component Cooling Pump Room" 8.17 CCNPP Calculation CA00695 Rev. 0, "Modification to Pipe Supports Associated with Salt Water Piping System" 8.18 CCNPP Calculation CA00698 Rev. 0, "Modification to Pipe Supports Associated with Salt Water Piping System" 8.19 CCNPP Calculation CA00699 Rev. 0, "Pipe Support Modification for Salt Water Piping System" 8.20 CCNPP Calculation CA00705 Rev. 0, "Review of Changes to Pipe Supports Configuration" 9.0 Attachments Attachment A: ME101 Benchmark Input (ILD-CALC-0013 ROBM.inp)

Attachment B: ME101 Pipe Clamp Input (ILD-CALC-0013_R0_CLAMP.inp)

Attachment C: ME101 Pipe Separation Input (ILD-CALC-0013_R0_S.inp)

Attachment D: ME101 Benchmark Output (ILD-CALC-0013_ROBM.out)

Attachment E: ME101 Pipe Clamp Output (ILD-CALC-0013_ROCLAMP.out)

Attachment F: ME101 Pipe Separation Output (ILD-CALC-0013_ROS.out)

Attachment G: CCNPP Correspondence Page 24 of 24

ENCLOSURE (7)

CALVERT CLIFFS PROCEDURE LR-01 (69 pages)

Calvert Cliffs Nuclear Power Plant, LLC December 6, 2013

CENG a joint venture of Consteltaton ., - eDF Calvert Cliffs Nuclear Power Plant TECHNICAL PROCEDURE LR-01 ON LINE LEAK REPAIRS TO VARIOUS PRESSURE RETAINING COMPONENTS Revision 00600 This Procedure is EXEMPT from 10 CFR 50.59 / 10CFR 72.48 Reviews Safety Related CONTINUOUS USE WO No.:

General Supervisor-Mechanical Maintenance

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I &2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 2 of 69 TABLE OF CONTENTS Sections Pages 1.0 P URP O S E .................................................................................... .. 4 2.0 APPLICABILITY/SCOPE............................................................... 4 3.0 REF ERENC ES ............................................................................... . 5 4.0 PR EREQ UIS ITES ........................................................................... 6 5.0 P REC A UT IONS ............................................................................. 9 6.0 PERFO R MANC E .......................................................... ........ 10 6.1 Leak Repair A ctivity ........................................................... 10 6.2 Post Leak Repair Activity .................................................... 10 7.0 POST-PERFORMANCE ACTIVITIES ...................... 11 8 .0 BA S E S .............................................................................................. 11 9 .0 RECO RDS ................................................................................... . . 11 Attachm ent 1, Packing Leaks ........................................................................ 12 , Flange/Bonnet Leaks, Wire Wrap with Cap Nuts and Wire Wrap with Slotted Studs and Cap Nuts ........................... 17 , Flange/Bonnet Leak Repairs Using Flat Face Pumping Method with Slotted Studs/Studs and Cap Nuts ..................... 25 , Flange Leaks: Flange Clamp Method ...................................... 29 , Piping/Fitting Leaks: Enclosures, Sealant Retaining Devices, P erim eter Seals ...................................................................... 34 , Pressure Seal Valve Bonnet Leak Repairs .................... 38 , Pre-Job Leak Repair Data Sheet .............................................. 43 , Post-Job Leak Repair Data Sheet.: ......................................... 45 , Repump Using Existing Penetrations ...................................... 46 0, Pre/Post job compressed air repair data ............................... 51 1, Compressed air-tubing less than 200 psig repair .................. 54 2, Valve Bonnet Gasket Repair (Drill And Tap) ......................... 56 Attachment 13, Valve / Line Kill - Hot Tap Ring ............................................. 63 4, Sealant Pumping Procedure .................................................. 68

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 3 of 69 LIST OF EFFECTIVE PAGES Cumulative Changes 0 Page No. Change No. Page No. Change No. Page No. Change No.

1 26 51 2 27 52 3 28 53 4 29 54 5 30 55 6 31 56 7 32 57 8 33 58 9 34 59 10 35 60 11 36 61 12 37 62 13 38 63 14 39 64 15 40 65 16 41 66 17 42 67 18 43 68 19 44 69 20 45 21 46 22 47 23 48 24 49 25 50

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 4 of 69 1.0 PURPOSE To provide instructions for temporary leak repairs to on-line components.

2.0 APPLICABILITY/SCOPE

1. This procedure applies to Units I and 2, Safety Related and Non-Safety Related components. Patches can only be installed on Non-Safety Related Compressed Air Tubing.
2. -This procedure applies to temporary leak repairs, unless otherwise covered by another approved Mechanical Maintenance technical procedure. Each attachment will not be used for every repair. Attachments that do not apply shall remain unused.
3. Temporary Repairs to safety related or ASME Section X1 components shall be implemented under CNG-CM-1.01-1004, Temporary Plant Configuration Change Process. Temporary Repairs to non-safety-related, non-ASME Section Xi components shall be implemented under a Work Order and controlled by MN-1-110. 1B2242]
4. Design Engineer review shall be completed prior to performance of any leak repairs made to main steam (System 83) components. [62066]
5. Pressure Boundary repairs on ASME Section XI piping requires NRC approval. Design Engineering shall be contacted. [522423
6. Leak repair fittings may be replaced with pipe plugs in NSR and non-Section X1 applications. [813529]
7. Attachment 1, Technical Procedure Step Deletion Screening Form (CNG-PR-1,01-1009), may be used to delete complete steps or partial wording within step(s). This attachment should be completed by the craft
8. All steps within a subsection must be performed in sequence unless otherwise noted in procedure body.
9. When a conditional step or subsection cannot be performed because the condition was not met, the step(s) shall be marked N/A.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 5 of 69

3.0 REFERENCES

3.1 Developmental

References:

1. MN-I -110, Procedure Controlled Activities
2. MN-1-101, Control of Maintenance Activities
3. CH-1-100, Controlled Materials Program
4. PM-1 Procurement Program Directive
5. Electric Power Research Institute (EPRI) NP-3111, Testing and Evaluation of On-Line Leak Sealing Methods
6. Leak Repairs Inc. (TEAM Inc.) Engineering Repair Procedures Manual ERPM-2
7. EPRI NP-6523-D, On-Line Leak Sealing, A Guide for Nuclear Power Plant Maintenance Personnel
8. USNRC Generic Letter 90-05, Guidance for Performing Temporary Non-Code Repair of ASME Code Class 1, 2, and 3 Piping. [B2242]
9. Leak Repair Inc. (Team Inc.), Engineering Design Manual, Revision 0, Dated July 21, 1989. [B2242]
10. NRC Information Notice 97-73 [11528]
11. MCR 93-047-004-00 [B13529]
12. ES199800191-000 Engineer evaluation to permit air tubing leak repairs
13. 92401 Instrument Tubing lnstallation (M500)
14. CNG-CM-1.01-1004, Temporary Plant Configuration Change Process
15. TRP-3422 TEAM inc Engineering repair procedure Valve / Line Kill -Hot Tap Ring
16. TRP-3410 TEAM inc Engineering repair procedure, Sealant Pumping Procedure 3.2 Performance

References:

1. CNG-CM-1.01-1004, Temporary Plant Configuration Change Process
2. Calvert Cliffs Industrial Safety Manual
3. SA-1-100, Fire Prevention
4. MN-I-110, Procedure Controlled Activities 3.3 Definitions
1. Mainlining - Sealant entering the main process stream

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 6 of 69 4.0 PREREQUISITES

4.1 Responsibilities

1. System Engineer
  • Ensure that a CR has been written.

" The System Engineer and Vendor representative shall inspect the leaking component and review methods to stop leakage, including an assessment of potential hazards to personnel and equipment.

  • When valve pressure boundary drilling is necessary, calculations or analysis shall be provided by leak repair vendor or valve vendor.

Alternatively, approval by the valve vendor is acceptable. Calculations or analysis shall be verified by System Engineer for non-safety related components or Design Engineer for safety-related components.

Calculations or analysis shall be included in the WO. [B2242]

" System Engineer and Vendor representative shalt determine maximum quantity of sealing compound which may be used and record quantity on Attachment 7, Pre-Job Data Sheet. [B13531]

" The Engineering Services Department could provide the System Engineer and the Design Engineer responsibilities as they are called out with-in LR-01.

2. Design Engineer Design Engineering involvement in leak repair process is required if repair affects a safety related or ASME Section Xl component and CNG-CM-1.01-1004, Attachment 5, Engineering Evaluation, shall be completed. In non-safety-related, non-ASME Section Xl repairs, Design Engineering involvement is not required, but is recommended if System Engineer needs assistance. [B2242]

Pressure boundary repairs on ASME Section X1 piping components need prior NRC approval. [82242]

Design Engineer review shall be completed prior to performance of any leak repairs made to main steam (System 83) components. [B20661

3. Vendor

" Vendor shall supply chemical analysis of sealing compounds and material certification for compounds, fittings, clamps, bars, valves, encapsulations, strongbacks and fasteners, if applicable.

  • Vendor shall supply details or sketches of enclosures, bars and clamps.
  • Vendor Representative shall install sealing device and Inject compound according to attachment listed by System Engineer on Attachment 7, Pre-Job Data Sheet.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 7 of 69 4.2 Personnel Requirements NOTE Two technicians (minimum) are required for each job. At least one technician should have a minimum of 1-1/2 years of leak sealing experience. Leak sealing contractor should be able to document this experience and to certify it to plant personnel.

1. Personnel requirements for all on line repairs except compressed air tubing.

A. Approved Vendor Technical Representatives (Two)

B. Qualified Sponsor C. Fire Watch, if required D. Qualified Cleanliness Inspector

2. Personnel requirements for compressed air tubing repair A. Two technicians, at least one qualified TUBE-01, Fabrication and Installation of Parker CPI and Swagelok Compression Fittings 4.3 Special Tools and Equipment Recommended:
1. Measuring and Test Equipment (M&TE)

M&TE for each type of leak repair is listed in applicable attachment.

2. Consumables Consumables for each type of leak repair are listed in applicable attachment.
3. Other Special Tools & Equipment Other special tools and equipment for each type of leak repair are listed in applicable attachment.

4.4 Spare Parts Recommended:

Recommended spare parts for each type of leak repair are listed in applicable attachment.

4.5 Documentation and Support Required:

1. Approved WO
2. Approved Engineering Service Package for Safety Related Repairs, if required
3. Repair and Replacement Plan for ASME Section XI Repairs, if required
4. Radiation work permit (RWP), if required
5. Fire Watch, if required

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-0I, Rev. 00600 Page 8 of 69 4.6 INITIAL CONDITIONS I. Attachment 7, Pre-Job Data Sheet, is complete and leak repair method is approved.

2. Operations approval on WO and MD-1-100 (if applicable), to start work.

CNG-CM-1.01-1004, Attachment 3, Temporary Alteration Form is complete and approved for safety related or ASME Section XI piping. [B2242].

3. Scaffolding is erected, if required.
4. Insulation is removed, if required.
5. Temporary lighting has been installed as required.
6. All working instrumentation (Vendor supplied and CCNPP equipment) has current verifiable calibration record.
7. General area of leaking component has been flagged off and caution signs posted, if required.
8. Fire Watch has been established, if required. [B1528]
9. A page check has been performed.

Prerequisites have been satisfied.

Date:

Job Supervisor

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 9 of 69 5.0 PRECAUTIONS

1. WHEN working in Radiologically Controlled Areas,
  • RWP requirements and good radiological practices shall be observed.

Fluids shall be treated as contaminated unless certified radiological clean by Plant Chemistry, Components shall be treated as contaminated unless certified radiologically clean by Radiation Protection.

Use of volatile liquids such as alcohol or acetone on contaminated items can generate airborne radioactivity. Contact Radiation Protection prior to use of volatile liquids on any contaminated equipment.

Exposure rates may change rapidly in specific areas. Take steps to maintain personnel exposure ALARA.

2. Consumables used in this procedure shall be approved for use according to CNG-EV-1.01-1002, Controlled Materials Management, and consumable materials considered hazardous (flammable, corrosive, reactive, toxic or listed as a hazardous waste), shall be stored, handled and disposed according to CH-1-101, Hazardous Waste Management.
3. M&TE used in this procedure shall be controlled and calibrated, as applicable, according to MN-2-100, Control and Calibration of Measuring and Test Equipment.
4. Personnel working in area of leak shall wear adequate protective equipment (protective gloves, face shield, safety glasses, appropriate clothing and a self contained supply of breathing air if necessary).
5. To prevent over-injection of leak sealing compound, Vendor representative and System Engineer shall determine maximum quantity of compound used.

[B1531]

6. The maximum injection pressure required to inject compound shall not be exceeded during sealant injection.
7. Hole drilling size(s) and location(s) shall be within requirements of calculations or analysis.
8. Sealant injection process should continue uninterrupted.
9. Injection valve shall always be closed before attaching sealant gun.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 10 of 69 6.0 PERFORMANCE 6.1 Leak Repair Activity

1. PERFORM leak repair according to attachment selected on Attachment 7, Pre Job Leak Repair Data Sheet OR 10, Pre Job / Post Job Compressed Air Repair Data Sheet.
2. IF leak repair is on 1 BDHV-211 piping, THEN PERFORM leak repair PER Attachment 13, Valve / Line Kill Hot Tap Ring, OR Attachment 14, Sealant Pumping Procedure.
3. IF all answers are no on Attachment 10, THEN PERFORM leak repair per Attachment 11, Compressed Air Tubing Less Than 200 PSIG Repair.

6.2 Post Leak Repair Activity

1. ENSURE Attachment 8, Post Job Leak Repair Data Sheet OR Attachment 10 is complete.
2. REMOVE temporary lighting or fixtures installed for this procedure,

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 11 of 69 7.0 POST-PERFORMANCE ACTIVITIES

1. A page check has been performed.
2. Post Maintenance activities shall be conducted per WO instructions.

COMPLETED PROCEDURE COMPLETED BY: DATE:

RESPONSIBLE SUPERVISOR: DATE:

8.0 BASES BASIS NUMBER REV. NO. BASIS B2242 0 CCSO Letter 90-685, Attachment 3 B2066 0 50.59 Evaluation B1528 1 NRC Information Notice 97-73, Fire Hazard in the Use of Leak Sealant B1529 1 MCR 93-047-004-00, Allow Installation of Permanent Pipe Plugs for Removed Leak Repair Fittings in NSR Applications B1531 1 SER 5-97, Liquid Leak Sealant Material Migrates Into Reactor Vessel Head Vent System 9.0 RECORDS

1. Records generated by this procedure shall be captured and controlled. Before transferring records to Record Management for retention, legibility and completeness of the record shall be verified by the transmitting organization.
2. Contents of this procedure shall be retained according to CNG-PR-3.01-1000, Records Management.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 12 of 69 ATTACHMENT 1 PACKING LEAKS Page 1 of 5 1.0 PURPOSE Provides instructions for on-line repair of valve packing leaks.

2.0 DEVELOPMENTAL REFERENCES Leak Repairs Inc. Procedure Nos. NP-2110, NP-2135, NP-2136, NP-2137 3.0 TOOLS AND EQUIPMENT REQUIRED

1. Air or battery powered drill motor, drill bits and taps
2. Leak Repairs Inc. hydraulic injection equipment (Nuclear) or equivalent
3. Injection valve(s) appropriate size
4. Leak Repairs Inc. Nuclear grade packing, or approved equivalent
5. Pipe plugs made from ASTM A105, A182, or A350 material for NSR and non-Section XI applications, if required [B1I529]

4.0 PERFORMANCE 4.1 Stuffing Box Preparation

1. OBTAIN stuffing box or bonnet wall thickness from equipment vendor technical manual and drawings.

Nominal wall thickness

2. MEASURE Outside Diameter (OD) of stuffing box and OD of packing follower, SUBTRACT and DIVIDE by 2 to determine average wall thickness.

Stuff. Box OD - Pack. Follower OD + 2=

Avg. wall Thick.

3. DETERMINE injection valve size.

Size:

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 13 of 69 ATTACHMENT 1 PACKING LEAKS Paae 2 of 5 1/16" NPT DRILL & TAP SEQUENCE CHART NOM. WALL THICKNESS under .262" to .301" to Over SEQUENCE .262" .300" .350" .350" 1: 1/8" Pilot Bit X X X 2: 1/4"' Finishing Bit x X X 3: 1(4" Bottom-Out Bit X 4: I116" NPT Starter Tap X X X 5: 1/16" NPTG Bottom-Out Tap X X "On wall thickness less then ,262" a hot tap bar will be used.

1/8" NPT DRILL & TAP SEQUENCE CHART NOM. WALL THICKNESS........._,_,..

under .275"to .351"to Over SEQUENCE .275"" .350" .500" .500" 1: 3/16" Pilot Bit X X X 2: "R" Finishing Bit X X X 3: "R" Bottom-Out Bit X 4: 1/8" NPT Starter Tap X X X 5: 1/8" NPTG Bottom-Out Tap X X

  • On wall thickness less than .275", refer to the 1/16" NPT Drill and Tap Sequence Chart.

1R4" NPT DRILL & TAP SEQUENCE CHART NOM, WALL THICKNESS under .400" to .475" to Over .550" SEQUENCE .400"" .475" .550' 1, 3/16" Pilot Bit X X X 2: "R" Finishing Bit X X X 3: 7/16" Bottom-Out Sit x 4: 1/4"NPT Starter Tap X X X 5: 1/16" NPTG Bottom-Out Tap x X

'On wall thickness less than .400", refer to the 1/8" NPT Drill and Tap Sequence Chart.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 14 of 69 ATTACHMENT I PACKING LEAKS Page 3 of 5 Subsection 4.1 (Continued)

NOTE:

Multiple injection ports may be required, however, the maximum number of ports listed on Attachment 7 shall not be exceeded without concurrence from all approval authorities.

4. LOCATE and CENTER PUNCH stuffing box OD as close to packing box center as possible.
5. SELECT appropriate size pilot drill bit for installed injection valve from Drill & Tap Sequence Charts.

. . .. .. .... .~C AUTIO N: .... .

Gland erosion or other circumstances may lead to unexpectedly drilling through stuffing box wall.

6. DRILL stuffing box, using a positive drill stop to prevent drilling completely through stuffing box wall.
7. IF premature drill-through is encountered, LOOSEN packing gland as necessary to redirect fluid or steam flow to allow injection valve installation. (MARK N/A if not required)
8. TAP stuffing box following selected Drill & Tap Sequence Chart.
9. INSTALL injection valve into stuffing box tapped hole and TIGHTEN securely.
10. OPEN injection valve.
11. SELECT appropriate size pilot bit and, using a stop and go motion, DRILL through stuffing box, exercising care not to hit valve stem.

WARNING:

Steam may occur when retracting drill and closing injection valve.

12. RETRACT drill and CLOSE injection valve,

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 15 of 69 ATTACHMENT I PACKING LEAKS Page 4 of 5 4.2 Sealant Injection CAUTION:

Follower nuts shall have a full nut thread engagement at all times.

1. CONTACT Operations for current system pressure and temperature indications.

A. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [B1531]

2. LOOSEN gland follower nuts approximately one quarter of exposed stud length (MARK N/A if not required).
3. ATTACH injection gun to injection valve.
4. OPEN injection valve.
5. INJECT packing until gland rises up and stops at follower nuts.
6. LOOSEN gland follower nuts approximately one quarter of exposed stud length (MARK N/A if not required).
7. INJECT packing until gland rises up and stops at follower nuts.
8. LOOSEN gland follower nuts approximately one quarter of exposed stud length (MARK N/A ifnot required).
9. CLOSE injection valve.
10. TIGHTEN gland follower nuts and compress packing.

CAUTION:

Follower nuts shall have a full nut thread engagement at all times.

11. REPEAT steps 4.2.7 through 4.2.10 until leak is stopped and stuffing box is full OR maximum quantity listed on Attachment 7 has been reached.
12. REMOVE injection gun.
13. LUBRICATE a drill-through plug with an approved lubricant and INSTALL plug into injection valve (MARK N/A if not required),
14. COMPLETE Attachment 8.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 16 of 69 ATTACHMENT 1 PACKING LEAKS Page 5 of 5 Iq" Injection Valve Installation Typical

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 &2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 17 of 69 ATTACHMENT 2 FLANGE/BONNET LEAKS, WIRE WRAP WITH CAP NUTS AND WIRE WRAP WITH SLOTTED STUDS AND CAP NUTS Page 1 of 8 1.0 PURPOSE Provides instructions for on-line injection of flange or valve body-to-bonnet connections that use cap nuts and wire wrap method for injection to stop leaks.

2.0 DEVELOPMENTAL REFERENCES Leak Repairs Inc. Procedure Nos. NP-2117, NP-2119, 3.0 TOOLS AND EQUIPMENT RECOMMENDED

1. Torque Wrench
2. Torque Multiplier, 4 to 1, if required
3. Leak Repairs Inc. Hydraulic Injection Equipment (NUCLEAR) or equivalent
4. Leak Repairs Inc. cap nuts, slotted studs, and injection valves or equivalent
5. Leak Repairs Inc. Nuclear grade sealant compound or approved equivalent
6. Wrapping Wire and/or Cable (appropriate size)
7. Stainless steel pins (provided by Leak Repairs Inc.), or equivalent 4.0 PERFORMANCE 4.1 Preparation
1. VERIFY flange or bonnet stud integrity before beginning work. Ifstuds are deteriorated, CONTACT System Engineer to determine if flange or bonnet studs need replacing.

REPLACE: Yes No Date:

System Engineer

2. TORQUE existing studs to value specified on Attachment 7.

All Studs Torqued Date Performed by

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 18 of 69 ATTACHMENT 2 FLANGE/BONNET LEAKS, WIRE WRAP WITH CAP NUTS AND WIRE WRAP WITH SLOTTED STUDS AND CAP NUTS Page 2 of 8 Subsection 4.1 (Continued)

3. SELECT and RECORD appropriate repair method:

Method A: Wire wrap and cap nuts.

Method B: Wire wrap with slotted studs and cap nuts.

VALVE Method A: Wire Wrap and Cap Nut Method TYPICAL

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 19 of 69 ATTACHMENT 2 FLANGE/BONNET LEAKS, WIRE WRAP WITH CAP NUTS AND WIRE WRAP WITH SLOTTED STUDS AND CAP NUTS Page 3 of 8 NOTE:

If Method A was selected, proceed to Step 4.2.

If Method B was selected, proceed to Step 4.3.

4.2 METHOD A, Wire Wrap and Cap Nuts Entire Subsection may be marked N/A if Method B is selected.

1. PERFORM for each cap nut installed.

A. REMOVE nut from one flange or bonnet stud.

B. LUBRICATE exposed stud(s) and Leak Repair injection cap(s) with an approved lubricant and INSTALL cap nut(s).

C. TORQUE cap nut(s) to value on Attachment 7.

All Cap Nuts Torqued Performed by

2. INSTALL open injection valves on installed cap nuts.
3. WIRE WRAP flange gap, TYING off wire at intervals, until wire is within 1/4 inch to 1/8 inch from edge of flanges.
4. INSTALL cable tensioning device or safety banding. (MARK N/A if not required)

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I &2 PRESSURE RETAINING COMPONENTS LR-0I, Rev. 00600 Page 20 of 69 ATTACHMENT 2 FLANGE/BONNET LEAKS, WIRE WRAP WITH CAP NUTS AND WIRE WRAP WITH SLOTTED STUDS AND CAP NUTS Page 4 of 8 Subsection 4.2 (Continued)

5. ADD injection gun static pressure to Maximum Design Injection pressure from Attachment 7, Line 14, to obtain maximum injection pressure.

Static press. (C.. J + Design Inj. press, () = Max. inject, press.

6. CONTACT Operations for current system pressure and temperature indications.

A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [B1531]

RGS HOLD POINT: Date:

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 21 of 69 ATTACHMENT 2 FLANGE/BONNET LEAKS. WIRE WRAP WITH CAP NUTS AND WIRE WRAP WITH SLOTTED STUDS AND CAP NUTS Page 5 of 8 Subsection 4.2 (Continued)

NOTE First injection gun hose to injection valve attachment is to valve farthest from leak.

CAUTION Maximum injection pressure or maximum sealant quantity shall not be exceeded.

7. PERFORM sealant injection using Injection Sequence illustration for each installed cap nut.

A. ATTACH injection gun hose to injection valve and INJECT sealant.

B. SHUT OFF injection valve and REMOVE injection gun.

A A IV

,.s. ~.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 22 of 69 ATTACHMENT 2 FLANGE/BONNET LEAKS, WIRE WRAP WITH CAP NUTS AND WIRE WRAP WITH SLOTTED STUDS AND CAP NUTS Page 6 of 8 Subsection 4.2 (Continued)

8. ALLOW adequate cure time from Attachment 7.
9. COMPLETE Attachment 8.

INJECTION VALVE _

SLOT INCAP NUT GAP Method B: Slotted Stud and Cap Nut TYPICAL

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 23 of 69 ATTACHMENT 2 FLANGE/BONNET LEAKS..WIRE WRAP WITH CAP NUTS AND WIRE WRAP WITH SLOTTED STUDS AND CAP NUTS Page 7 of 8 4.3 METHOD B, Wire Wrap with Slotted Studs and Cap Nuts Entire Subsection may be marked N/A if Method A selected.

1. PERFORM for each wire wrap with slotted studs and cap nuts:

A. REMOVE nut(s) and stud from one location only.

B. LUBRICATE slotted stud and contact surface of cap nut with an approved lubricant.

C. INSTALL slotted stud, cap nut and nut (if required).

D. TORQUE cap nut to value from Attachment 7.

All Cap Nuts Torqued:

Performed by

2. INSTALL open injection valves on all cap nuts.
3. INSTALL isolation pins on both sides of leaking area. (MARK N/A if not required)
4. WIRE WRAP flange gap, TYING off wire at intervals until wire is within 1/4 inch to 1/8 inch from edge of flanges.
5. INSTALL cable tensioning device. (MARK N/A if not required).
6. ADD injection gun static pressure to Maximum Design Injection Pressure from Attachment 7, Line 14, to obtain maximum injection pressure.

Static press. + Design inj. press, Q.._)

+_ = Max. inject, press.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 24 of 69 ATTACHMENT 2 FLANGE/BONNET LEAKS, WIRE WRAP WITH CAP NUTS AND WIRE WRAP WITH SLOTTED STUDS AND CAP NUTS Page 8 of 8 Subsection 4.3 (Continued)

7. CONTACT Operations for current system pressure and temperature indications.

A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [B13531]

RGS HOLD POINT: Date:

NOTE:

First injection hose to injection valve attachment is to valve farthest from leak.

...... ijetin.p L r or m m CAUTION Maximum injection pressure or maximum sealant quantity shall not be exceeded.,.... ..

8. PERFORM sealant injection using Injection Sequence illustration for each installed cap nut.

A. ATTACH injection gun hose to injection valve and INJECT sealant.

B. SHUT OFF injection valve and REMOVE injection gun.

9. ALLOW adequate cure time from Attachment 7.
10. COMPLETE Attachment 8.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 &2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 25 of 69 ATTACHMENT 3 FLANGE/BONNET LEAK REPAIRS USING FLAT FACE PUMPING METHOD WITH SLOTTED STUDS/STUDS AND CAP NUTS Page 1 of 4 1.0 PURPOSE Provides instructions for on-line repairs to flange or valve body-to-bonnet connection leaks using slotted studs or studs and cap nut method without wire wrapping.

2.0 DEVELOPMENTAL REFERENCES Leak Repairs Inc. Procedure NP-2116 3.0 TOOLS AND EQUIPMENT RECOMMENDED

1. Torque wrench
2. Torque Multiplier 4 to 1 if required
3. Leak Repairs Inc. Hydraulic Injection equipment (NUCLEAR) or equivalent
4. Leak Repairs Inc. Cap nuts, slotted studs, and injection valves or equivalent
5. Leak Repairs Inc, Nuclear grade sealant compound or approved equivalent
6. Peening gun
7. Pipe plugs made from ASTM Al 05, Al 82 or A350 material for NSR and non ASME Section Xl, as appropriate. [11529]

4.0 PERFORMANCE 4.1 Preparation

1. VERIFY flange or bonnet stud integrity before beginning work. If studs are deteriorated, CONTACT System Engineer to determine if flange or bonnet studs need replacing. [B22421 REPLACE: Yes No DATE:

System Engineer

2. TORQUE existing studs to value from Attachment 7.

All studs torqued: Date Performed by

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 26 of 69 ATTACHMENT 3 FLANGEIBONNET LEAK REPAIRS USING FLAT FACE PUMPING METHOD WITH SLOTTED STUDS/STUDS AND CAP NUTS Page 2 of 4 Subsection 4.1 (Continued)

3. INSPECT flange or bonnet for gaps that would allow sealant to extrude.

A. IF gap(s) are found that sealant may extrude, THEN CONTACT RGS for direction to peen gap(s) closed.

4. ADD injection gun static pressure to Maximum Design Injection Pressure from Attachment 7, Line 14, to obtain maximum injection pressure.

Static press. (__J + Design Inj. press. L.) = Max. inject, press.

4.2 Slotted Stud or Stud and Cap Nut Installation

1. REMOVE nut(s) and stud from one location only.
2. LUBRICATE slotted stud or stud and contact surfaces of cap nut with an approved lubricant.
3. INSTALL a slotted stud/stud and cap nut, and nut, if required.
4. TORQUE cap nut to value on Attachment 7.
5. REPEAT Steps 4.2.1 through 4.2.4 on every other stud.

Number of slotted studs/studs and cap nuts installed:

All Cap Nuts Torqued Date Performed by

6. INSTALL injection valves on all cap nuts.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 27 of 69 ATTACHMENT 3 FLANGE/BONNET LEAK REPAIRS USING FLAT FACE PUMPING METHOD WITH SLOTTED STUDS/STUDS AND CAP NUTS Page 3 of 4 4.3. Sealant Injection 1 CONTACT Operations for current system pressure and temperature indications.

A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [1B15311 RGS HOLD POINT: Date:

NOTE:

First injection hose attachment is to injection valve farthest from leak.I CAUTION Maximum injection pressure or maximum sealant quantity shall not be exceeded.

2. PERFORM sealant injection using Injection Sequence illustration for each installed cap nut.

A. ATTACH injection gun hose to injection valve and INJECT sealant.

B. SHUT OFF injection valve and REMOVE injection gun.

A A " "  : A. i. .1I

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 28 of 69 ATTACHMENT 3 FLANGE/BONNET LEAK REPAIRS USING FLAT FACE PUMPING METHOD WITH SLOTTED STUDS/STUDS AND CAP NUTS Page 4 of 4 Subsection 4.3 (Continued)

3. PEEN at areas of sealant extrusion.
4. ALLOW adequate cure time from Attachment 7.
5. COMPLETE Attachment 8.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 29 of 69 ATTACHMENT 4 FLANGE LEAKS: FLANGE CLAMP METHOD Page 1 of 5 1.0 PURPOSE Provides instructions for on-line repairs to flange or valve body-to-bonnet connection leaks using a clamp device supplied by an approved Vendor.

2.0 DEVELOPMENTAL REFERENCES Leak Repairs Inc. Procedure NP-2114 3.0 TOOLS AND EQUIPMENT

1. Torque Wrench
2. Torque Multiplier 4 to 1, if required
3. Leak Repairs Inc. Hydraulic injection equipment (NUCLEAR) or equivalent
4. Leak Repairs Inc. clamp device, fasteners and injection valves or equivalent
5. Leak Repairs Inc. Nuclear grade sealant compound or approved equivalent
6. Pipe plugs made from ASTM Al05, A182 or A350 material for NSR and non-Section XI applications, if required. EB1529]

4.0 PRECAUTIONS

1. VERIFY flange or bonnet stud integrity before beginning work. Ifstuds are deteriorated, CONTACT System Engineer to determine if flange or bonnet studs need replacing. (MARK N/A if not required). [B22421 REPLACE: Yes No Date System Engineer

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 30 of 69 ATTACHMENT 4 FLANGE LEAKS: FLANGE CLAMP METHOD Page 2 of 5 5.0 PERFORMANCE 5.1 Preparation

1. TORQUE existing studs to value on Attachment 7.

All studs torqued: Date Performed by NOTE Design Engineering must review and approve proposed vendor design, materials and method of manufacture prior to installation for SR components.

2. APPLY a thin coating of an approved lubricant to all threaded fasteners.
3. INSTALL approved sealant device (clamp),

NOTE Injection valves on sealant device located directly at leak area shall be left in the open position until all other valves have been injected with sealant.

4. TIGHTEN device fasteners, ENSURING device pulls up evenly.
5. ADD injection gun static pressure to Maximum Design Injection Pressure from Attachment 7, Line 14, to obtain maximum injection pressure.

Static press. (_) + Design inj. press, (_) = Max, inject, press.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 31 of 69 ATTACHMENT 4 FLANGE LEAKS: FLANGE CLAMP METHOD Page 3 of 5 5.2 Sealant Injection

1. CONTACT Operations for current system pressure and temperature indications.

A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [B115311 RGS HOLD POINT: Date:

NOTE:

First sealant injection is to injection valve OPPOSITE leak.

CAUTION:

Maximum injection pressure or maximum sealant quantity shall not be exceeded,

2. PERFORM for each injection valve, beginning with injection valve OPPOSITE leak.

A. ATTACH injection gun to injection valve B. OPEN injection valve and INJECT sealant.

C. CLOSE injection valve and REMOVE injection gun.

3. ALLOW adequate cure time from Attachment 7.
4. COMPLETE Attachment 8.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 32 of 69 ATTACHMENT 4 FLANGE LEAKS: FLANGE CLAMP METHOD Page 4 of 5 CRUNCH GROOVE CLAMP Clamp Device Designs TYPICAL

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 33 of 69 ATTACHMENT 4 FLANGE LEAKS: FLANGE CLAMP METHOD Page 5 of 5 Injection Gun Attachment TYPICAL

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 &2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 34 of 69 ATTACHMENT 5 PIPING/FITTING LEAKS: ENCLOSURES, SEALANT RETAINING DEVICES PERIMETER SERALS Page 1 of 4 1.0 PURPOSE Provides instructions for on-line repairs to piping and-fittings using encapsulations and sealant retaining devices.

2.0 DEVELOPMENTAL REFERENCES Leak Repairs Inc. Procedures NP-2115, NP-2128, NP-2130, and NP-2133 3.0 TOOLS AND EQUIPMENT REQUIRED

1. Leak Repairs Inc. Hydraulic injection equipment (NUCLEAR) or equivalent
2. Leak Repairs Inc, Enclosures, sealant retaining devices, strongbacks and injection valves or equivalent
3. Leak Repairs Inc. Nuclear grade sealant compound or approved equivalent Sealant Retaining Devices Typical

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev, 00600 Page 35 of 69 ATTACHMENT 5 PIPINGFITTING LEAKS: ENCLOSURES, SEALANT RETAINING DEVICES, PERIMETER SEALS Page 2 of 4 4.0 PERFORMANCE 4.1 Preparation

1. IF hot tap ring is NOT used, THEN TORQUE all flange bolts to value on Attachment 7 (MARK N/A if not required).

All flange bolts torqued: Date:

Performed by

2. INSTALL soft patch as stopgap measure to slow leak, (MARK N/A if not required)
3. LUBRICATE all fasteners with an approved lubricant.
4. IF hot tap ring is NOT used, THEN INSTALL sealant retaining device with injection valves over leaking component open, NOTE:

Installation of a Hot Tap Ring (HTR) requires that the HTR be injected with the appropriate sealant, and allowing the sealant to cure prior to performing the drill-thru.

5. IF a hot tap ring is used, THEN INSTALL sealant retaining device with injection valve over leaking component.

A. ATTACH the hydraulic injection gun hose to the injection valve.

B. INJECT sealant until the HTR has sufficient coverage to allow for the drill-thru.

C. CLOSE the injection valve and remove the hydraulic injection gun hose.

D. ALLOW sealant time to cure prior to performing the drill-thru step.

6. TIGHTEN sealant retaining device studs, starting from middle of side bars, and work outwards until all fasteners are securely tightened.
7. IF a hot tap ring is used, THEN SELECT appropriate size pilot drill bit for installed hot tap ring from Drill & Tap Sequence Charts.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 36 of 69 ATTACHMENT 5 PIPING/FITTING LEAKS: ENCLOSURES, SEALANT RETAINING DEVICES PERIMETER SEALS Page 3 of 4

8. IF a hot tap ring is used, THEN ENSURE a positive drill stop is installed on the drill to prevent drilling completely through pipe.
9. IF a hot tap ring is used, THEN DRILL through the first pipe wall.
10. IF a hot tap ring is used, THEN REMOVE drill and CLOSE injection valve.

NOTE:

Ifperimeter seal enclosure used has a primary and a secondary seal, the primary (inner) seal should be injected first.

11. ADD injection gun static pressure to Maximum Design Injection Pressure listed on Attachment 7, Line 15, to obtain maximum injection pressure.

Static press. (__) + Design inj. press. (_ = Max. inject, press.

4.2 Sealant Injection

1. CONTACT Operations for current system pressure and temperature indications.

A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [81531]

RGS HOLD POINT: Date:

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 37 of 69 ATTACHMENT 5 PIPING/FITTING LEAKS: ENCLOSURES. SEALANT RETAINING DEVICES PERIMETER SEALS Page 4 of 4 I NOTE:

First sealant injection is to injection valve OPPOSITE leak.

t CAUTION

,Maximum injection pressure or maximum sealant qua ntity.,sh.a.ltl noobe exceeded.'

I

2. PERFORM for each injection valve, beginning with injection valve OPPOSITE leak.

A. ATTACH injection gun to injection valve.

B. OPEN injection valve and INJECT sealant.

C. CLOSE injection valve and REMOVE injection gun.

3. ALLOW adequate cure time from Attachment 7.
4. PLUG the back of the injection valve(s) with a Drill-Thru Safety Plug (DTSP) or approved plug.
5. COMPLETE Attachment 8.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 38 of 69 ATTACHMENT 6 PRESSURE SEAL VALVE BONNET LEAK REPAIRS Page 1 of 5 1.0 PURPOSE Provides instructions for on-line leak repairs to pressure seals on pressure seal valves.

2.0 DEVELOPMENTAL REFERENCES Leak Repairs Inc. Procedures NP-2142, NP-2143, NP-2144.

3.0 TOOLS AND EQUIPMENT RECOMMENDED

1. Air or battery powered drill motor, drill bits and taps
2. Leak Repairs Inc. hydraulic injection equipment (NUCLEAR) or equivalent
3. Leak Repairs Inc. injection valves (appropriate size) or equivalent
4. Leak Repairs Inc. Nuclear grade sealant or approved equivalent 4.0 PERFORMANCE 4.1 Preparation NOTE:

Dimensions may be obtained from valve manufacturer if required dimensions are not in valve technical manual.

Attachment 6 Worksheet is an example only. Actual injection valve locations are determined on a case-by-case basis.

1. Valve dimensions have been obtained and Attachment 6 Worksheet has been completed.
2. Drilling locations and number of installed injection valves has been approved by System Engineer or Design Engineer if MD-I-100 is required. [B2242]

Date:

System Engineer or Design Engineer

3. DETERMINE injection valve size.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 39 of 69 ATTACHMENT 6 PRESSURE SEAL VALVE BONNET LEAK REPAIRS Page 2 of 5 1/16" NPT DRILL & TAP SEQUENCE CHART NOM. WALL THICKNESS under .262" to .301" to Over SEQUENCE .262"* .300" .350" .350" 1: 1/8" Pilot Bit X X X 2: 1/4" Finishing Bit X X X 3: 1/4" Bottom-Out Bit X 4: 1/16"NPT Starter Tap X X X 5: 1/16"NPTG Bottom-OutTap X X

'On wall thickness less than .262" a hot tap bar will be used.

1/8" NPT DRILL & TAP SEQUENCE CHART NOM. WALL THICKNESS under .275" to .351" to Over.

SEQUENCE .275"* .350" .500" 500" 1: 3/16" Pilot Bit x x x 2: "R" Finishing Bit X X x 3: "R" Bottom-Out Bit X 4: 1/8'NPT Starter Tap x x x 5: 1/8" NPTG Bottom-Out Tap X X

  • On wall thickness less than .275", refer to the 1/16V NPT Drill and Tap Sequence Chart.

1/4" NPT DRILL & TAP SEQUENCE CHART NOM. WALL THICKNESS under .400" to .475" to Over SEQUENCE .400"* .475" .550" .550" 1: 3/16" Pilot Bit X X X 2: "R" Finishing Bit x x x 3: 7116" Bottom-Out Bit . . .. _ X 4: 1/4" NPT Starter Tap _.X X X 5: 1/16" NPTG Bottom-Out Tap X X

  • On wall thickness less than .400", refer to the 1/8" NPT Drill and Tap Sequence Chart.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 40 of 69 ATTACHMENT 6 PRESSURE SEAL VALVE BONNET LEAK REPAIRS Page 3 of 5 4.2 Valve Body Preparation

1. LOCATE and CENTER PUNCH valve body at location(s) specified on Worksheet.
2. SELECT appropriate size pilot drill bit for injection valve size to be installed from Drill & Tap Sequence Chart.
3. DRILL valve body, using a positive drill stop to prevent drilling completely through valve body wall.
4. TAP valve body using drill and tap sequence chart.
5. INSTALL injection valve into valve body and TIGHTEN securely.
6. CLOSE injection valve.

NOTE:

Valves 4-inches and below, a minimum of two drill and tap holes may be required.

Valves above 4-inches, a minimum of four drill and tap holes may be required.

7. DRILL and TAP additional locations specified, beginning OPPOSITE original location.
8. INSTALL and TIGHTEN injection valves in all drilled and tapped holes,
9. OPEN an injection valve.
10. SELECT appropriate size pilot bit and, using a stop and go motion and injection valve as a drill guide, DRILL through valve body, exercising care not to hit valve pressure seal ring.
11. RETRACT drill and CLOSE injection valve.
12. REPEAT steps 4.2.9 through 4.2.11 for remaining injection valves.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 41 of 69 ATTACHMENT 6 PRESSURE SEAL VALVE BONNET LEAK REPAIRS Page 4 of 5 Subsection 4.2 (Continued)

13. ADD injection gun static pressure to Maximum Design Injection Pressure from Attachment 7, Line 14, to obtain maximum injection pressure.

Static press. Q..) + Design inj. press. Q__) = Max. inject, press.

4.3 Sealant Injection

1. CONTACT Operations for current system pressure and temperature indications.

A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B, VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [B1531]

RGS HOLD POINT: Date:

NOTE:

First injection gun attachment and sealant injection is to injection valve OPPOSITE leak.

CAUTION:

Maximum injection pressure or maximum sealant quantity shall not be exceeded.

2. PERFORM for each injection valve, beginning with injection valve OPPOSITE teak.

A. ATTACH injection gun to injection valve.

B. OPEN injection valve and INJECT sealant.

C. CLOSE injection valve and REMOVE injection gun.

3. ALLOW adequate cure time from Attachment 7.
4. COMPLETE Attachment 8.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 42 of 69 ATTACHMENT 6 PRESSURE SEAkL VALVE BONNET LEAK REPAIRS Page 5 of 5 WORKSHEET BONNET RE GASI RETAI 5p, AR Valve EIN #

Valve Manufacturer Valve Size Dimension "A" Dimension "B" Total number of injection valves to be installed

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 43 of 69 ATT-ACHMENT 7 PRE-JOB LEAK REPAIR DATA SHEET Page 1 of 2 INITIAL PUMP REPUMP

1. Component EIN
2. Component Description
3. Pressure Boundary Leak Description
4. Component Line Class
5. Design Pressure
6. Design Temperature
7. Normal Service Pressure
8. Normal Service Temperature
9. LR-1 Attachment Selected
10. Torque Value, if required
11. Nuclear Grade Sealant Type: P.O.#:

Cure Time:

System Requirements for Sealant System Temperature Range:

Application Pressure Range:

12. Chemistry Approved Date: CML#:
13. Maximum Sealant Amount Allowed to tubes be Injected [81531]
14. Maximum Number Injection Ports
15. Maximum Design Injection Pressure psi Pressure Data Source
16. Repair/Replacement Plan Number
17. Temporary Alteration Tag Number, if required

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 44 of 69 ATTACHMENT 7 PRE-JOB LEAK REPAIR DATA SHEET Page 2 of 2

18. Verify leak repair method or clamping device is designed according to TEAM Inc.

(Leak Repair Inc.) Engineering Design Manual, Revision 0, dated July 21, 1989.

Verify design inputs used by Leak Repair Inc. are accurate, Design Engineering shall review for safety related components or for main steam components.

[B2242] [B2066]

Design Engineer or System Engineer

19. Verify piping wall thickness is sufficient to withstand forces generated by clamp rings and enclosures. [B2242]

Design Engineer or System Engineer

20. Potential impact on downstream equipment has been evaluated. [B1531]

System Engineer

21. Vendor proposal shall be reviewed and approved by System Engineer or, if MD-I-100 is required, by Design Engineer. Component hangers and restraints shall be evaluated for additional weight of sealant retaining device. Installation of additional supports may be required before sealant retaining device is installed.

[B2242]

System Engineer

22. All data has been reviewed and approved by System Engineer or, if required, by Design Engineer.

Planner Engineer (SE or DES)

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 &2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 45 of 69 ATTACHMENT 8 POST JOB LEAK REPAIR DATA SHEET Page 1 of 1

1. Amount Sealant Compound Used tubes
2. IF applicable, INSTALL Temporary Alteration Tags and PROCESS the temporary alteration per MD-1-100, Temporary Alterations. [B2242]
3. VERIFY leak stopped. If leak still Date exists, CONTACT System Engineer for Time use of Attachment 9, Repump Using Existing Penetrations.
4. Work Completed by:

Vendor Representative NOTE:

Leak stoppage verification in High Radiation Areas may be performed by means other than visual re-inspection.

5. RE-VERIFY leak is stopped 24 - 48 Verified By:

hours after time in step 3. (MARK N/A if not required)

RECORD time and date. Date Time

6. INITIATE Condition Report for WO to perform a permanent repair.

CR/WO Number:

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 46 of 69 ATTACHMENT 9 REPUMP USING EXISTING PENETRATIONS Page 1 of 5 1.0 PURPOSE Provide instructions for repumping of existing penetrations.

2.0 DEVELOPMENTAL REFERENCES Leak Repairs Inc. Procedures NP-2138, NP-2149, NP-2145, and NP-2129 3.0 TOOLS AND EQUIPMENT REQUIRED

1. Leak Repairs Inc. Hydraulic injection equipment (NUCLEAR) or equivalent
2. Leak Repairs Inc. Enclosures, sealant retaining devices, strongbacks and injection valves or equivalent
3. Leak Repairs Inc. Nuciear grade sealant compound or approved equivalent 4.0 INITIAL CONDITIONS
1. System and Design Engineering has evaluated the recurrent leak and has determined it is safe to repump.

Date System Engineer

2. Attachment 7 has been completed for repump.

Initial Conditions have been met.

Date Sponsor

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 47 of 69 ATTACHMENT 9 REPUMP USING EXISTING PENETRATIONS Page 2 of 5 5.0 PERFORMANCE NOTE:

Subsection used for repumplng shall be the same as used for original repair. Subsections not used should be marked N/A.

5.1 Valve Packing

1. INSTALL high pressure gland assembly to existing injection valve.

(MARK N/A if not required)

2. INSTALL injection valve into drill through plug.

3 PROCEED with drill-through by opening injection valve and closing valve after drill through is complete.

4. CONTACT Operations for current system pressure and temperature indications.

A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [B1531]

RGS HOLD POINT: Date:

5. ATTACH injection pump to injection valve and INJECT sealant until stuffing box is filled, gland is fully extended, and leak is contained OR maximum amount of sealant allowed is injected..
6. CLOSE injection valve.
7. PLUG back of injection valve OR REMOVE injection valve and INSTALL safety plug.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I &2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 48 of 69 ATTACHMENT 9 REPUMP USING EXISTING PENETRATIONS Page 3 of 5 5.2 Wire Wrap

1. TIGHTEN all flange or bonnet studs wrench tight.

NOTE:

If more than one cap nut and stud assembly requires replacement, replacement must be done one at a time,

2. BEGIN with stud nearest teak, REMOVE existing cap nut and stud assembly.
3. CLEAN existing hole in flange assembly and REPLACE with clean cap nut and stud assembly.
4. INSTALL cable tensioning device or banding, if applicable.
5. CONTACT Operations for current system pressure and temperature indications.

A. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [B1531]

6. Starting at cap nut and stud assembly in area of least leakage, ATTACH injection gun to injection valve and INJECT sealant until leak is contained or pressure is obtained.
7. After cure time has elapsed, REPEAT injection at all remaining cap nut and stud assemblies until leak is contained or pressure is obtained. (N/A if injecting only one assembly.)

5.3 Pressure Seal Valve Repump

1. INSTALL and TIGHTEN adapters to all existing injection valves, if applicable.
2. INSTALL high pressure packing gland assembly at first valve to be drilled through, if applicable.
3. INSTALL injection valve, if necessary.
4. PROCEED with drill through by opening injection valve and then CLOSING valve after drill through is complete. REPEAT for all remaining valves.
5. INSTALL hydraulic injection pump on valve 180 degrees from valve with worst leak.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev, 00600 Page 49 of 69 ATTACHMENT 9 REPUMP USING EXISTING PENETRATIONS Page 4 of 5 Subsection 5.3 (Continued)

6. CONTACT Operations for current system pressure and temperature indications.

A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11, [B31531]

RGS HOLD POINT: Date:

7. PUMP until leak is contained or pressure is obtained, REPEAT for all remaining valves,

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 50 of 69 ATTACHMENT 9 REPUMP USING EXISTING PENETRATIONS Page 5 of 5 5.4 Sealant Retaining Device Repump I. TIGHTEN all existing bolting wrench tight.

2. ADAPT to existing fitting and DRILL-THROUGH.
3. IF drill-through safety plugs are present, THEN DO the following:

(MARK N/A if not required.)

A. FINISH tapping plug, B. INSTALL injection valve.

C. PROCEED with drill-through.

4. CONTACT Operations for current system pressure and temperature indications, A. RECORD the following:

System pressure System temperature Operations HOLD POINT: Date:

B. VERIFY current system operating conditions are within required service pressure and service temperature ranges listed on Attachment 7, Line 11. [B31531]

RGS HOLD POINT: Date:

5. INSTALL injection pump to injection valve with least amount of leakage and INJECT sealant until leak is contained or pressure is obtained.
6. REPEAT as necessary for all remaining valves. (MARK N/A if not required.)
7. AFTER cure time has elapsed, REPEAT injection at all remaining injection valves until leak is contained or pressure is obtained.(MARK N/A if injecting only one assembly)

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 51 of 69 ATTACHMENT 10 PRE JOB/POST JOB COMPRESSED AIR REPAIR DATA SHEET Page 1 of 3 SCOPE:

This Attachment shall be used to identify the job scope and determine if a temporary repair patch can be installed under this procedure.

JOB SCOPE:

1. Repair Location:
2. Hole Size:

Actual Maximum Axial Length inches.

Actual Maximum Circumferential Length inches.

3. Tubing out side diameter and material composition:

4, Immediate downstream equipment loads that will be affected during permanent repair:

Person Completing Sheet Date:

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 52 of 69 ATTACHMENT 10 PRE JOB/POST JOB COMPRESSED AIR REPAIR DATA SHEET Page 2 of 3 TABLE 1:

Circle the tubing size and determine if the actual maximum axial and circumferential lengths exceed the allowed maximum lengths stated in the below table

[ES199800191]:

TUBESIZE MAXIMUM MAXIMUM ALLOWED (0. D.) ALLOWED AXIAL CIRCUMFERENTIAL LENGTH (inches) LENGTH (inches) 1/8 inch 0.39 0.13

'A inch 0.78 0.26 3/8 inch 1.18 0.39 1

inch 1.57 0.52 5/8 inch 1.96 0.65 14 inch 2.36 0.79 7/8 inch 2.75 0.92 1 inch 3.14 1.0 APPLICABILITY SCREEN:

The purpose of this screen is to determine if a temporary patch is permitted under this procedure. Answer the following questions.

1. Is tubing SR? YES/NO.
2. Does actual maximum hole size (Axial or Circumferential) exceed the criteria of Table 1 for the associated tubing size? YES/NO
3. For patches that will not be located in the confines of a tubing tray, is there already a patch installed on the same span of tubing (between adjacent tubing supports) as the proposed patch? YES/NO Person completing screen question!s -Date

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 53 of 69 ATTACHMENT 10 PRE JOB/POST JOB COMPRESSED AIR REPAIR DATA SHEET Page 3 of 3 ACTIONS:

Ifany of the questions are answered YES this procedure cannot be used.

Ifall answers are NO, then Attachment 11 of this procedure can be used.

1. Patch method used. I or 2.
2. IF applicable, INSTALL Temporary Alteration Tags and PROCESS the temporary alteration per MD-I-100, Temporary Alterations.
3. VERIFY leek stopped.

Verify By:

4. IF leak still exists, THEN CONTACT System Engineer.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 54 of 69 ATTACHMENT 11 COMPRESSED AIR TUBING LESS THAN 200 PSIG REPAIR Page 1 of 2 PATCH TYPE I SCOPE:

Patch type 1 is typically used in smaller tube leaks. The determining factor as to whether Patch type 1 or Patch 2 will be used is the ability of the neoprene tape to seal the hole. Ifthe hole is too big, the force of air rushing from the hole will prevent the installation of Patch type 1. In those instances, Patch type 2 should be used.

MATERIALS:

1. Neoprene tape
2. Hose clamp.

INSTALLATION GUIDELINES:

1. INSTALL neoprene tape at hole location,
2. WHEN air leak is contained, THEN INSTALL and tighten a hose clamp over the hole location.
3. IF tubing vibrations is present and hose clamp is impacting against adjacent tubing, THEN INSTALL tygon tubing 8 inches or less in length to prevent the hose clamp from damaging the adjacent tubing.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 55 of 69 ATTACHMENT 11 COMPRESSED AIR TUBING LESS THAN 200 PSIG REPAIR Page 2 of 2 PATCH TYPE 2 SCOPE:

Patch type 2 is typically used for larger tube leaks. The determining factor as to whether patch type I or patch type 2 will be used is the ability of the neoprene tape used in patch type 1 to seal the hold. Ifthe hole is too big, the force of air rushing from the hole will prevent the installation of patch type 1. In those instances patch type 2 should be used.

MATERIALS:

1. Neoprene or Red Rubber Sheets (or equivalent)
2. Hose clamps INSTALLATIONS GUIDELINES:
1. INSTALL neoprene or red rubber sheet (or equivalent) at the hole location. (Refer to Table 1 for dimensions)
2. INSTALL hose clamp over hole location and at both ends of neoprene or red rubber sheet (or equivalent). (Refer to Table 1 for dimensions)
3. IF tubing vibrations is present and hose cdamp is impacting against adjacent tubing, THEN INSTALL tygon tubing 8 inches or less in length to prevent the hose clamp from damaging the adjacent tubing.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 56 of 69 ATTACHMENT 12 VALVE BONNET GASKET REPAIR (DRILL AND TAP)

Page 1 of 7 1.0 PURPOSE To provide instructions for on-line leak repairs between bonnet and valve body.

2.0 DEVELOPMENTAL REFERENCES Team Industrial Services Inc. Procedure TRP-3009 Rev. 0 3.0 TOOLS AND EQUIPMENT

1. Pneumatic or battery powered drill
2. Hose for Pneumatic too) operation
3. Drill bits
4. Tap(s)
5. Hydraulic Injection Gun
6. Hand tools to install equipment
7. Hydraulic injection Gun (NUCLEAR) or equivalent
8. Ball valves (appropriate size) or equivalent
9. Nuclear grade sealant or approved equivalent
10. High-Pressure Packing Gland (HPPG)

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 57 of 69 ATTACHMENT 12 VALVE BONNET GASKET REPAIR (DRILL AND TAP)

Page 2 of 7 4.0 PERFORMANCE 4.1 Valve Body Preparation

1. OBTAIN a controlled copy of a cross-sectional drawing of the valve to be repaired.

NOTE:

Bail valve type injection valves are the preferred method when installing injection valves.

The use of ball valves is dependant on the materials of composition for compatibility with the leak source system pressure and temperature.

2. OBTAIN the correct amount of ball valve type injection valves.
3. ENSURE Engineering has determined the allowable amount of sealant required to seal the leak.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 58 of 69 ATTACHMENT 12 VALVE BONNET GASKET REPAIR (DRILL AND TAP)

Page 3 of 7 4.2 Sealant Injection

1. WHEN the HPPG assembly will be used, THEN refer to the applicable Team Industrial Services, INC. chart listed below:

"116" NPT DRILL & TAP SEQUENCE CHART

.250" to .300" .301" to .350" Over .350" SEQUENCE Wall Thickness Wall Thickness Wall Thickness 1: 1/8" Pilot Bit (Optional) X, X x 2: "D" Finishing Bft X X X 3: "D" Bottom-Out Bit X 4: 1/16" NPT Starter Tap X X x 5: 1/16" NPT Bottom-Out Tap X X A wall thickness less than .250" requires the use of a hot tap ring for drilling or some other method of sealing the leak is recommended.

18" NPT DRILL &TAP SEQUENCE CHART

.275" to.350" .351'to .50o" Over .500" SEQUENCE Wall Thickness Wall Thickness Wall Thickness 1: 3/16" Pilot Bit (Optional) X X X 2: "R" Finishing Bit X X X 3: "R" Bottom-Out Bit X 4: 1/8"NPT Starter Tap X X X 5: 1/8' NPT Bottom-Out Tap X X On wall thickness less than .275", refer to the 1/16" NPT Drill and Tap Sequence Chart.

1/4" NPT DRILL & TAP SEQUENCE CHART

.400" to .475" .475" to .550" Over .550" SEQUENCE Wall Thickness Wall Thickness Wall Thickness 1: 3/16" Pilot Bit X X X 2: 7/16" Finishing Bit X X X 3: 7/16" Bottom-Out Bit X 4: 1/4" NPT Starter Tap X X x 5: 1/4" NPT Bottom-Out Tap X X

  • On wall thickness less than .400", refer to the 1/8" NPT Drill and Tap Sequence Chart.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 59 of 69 ATTACHMENT 12 VALVE BONNET GASKET REPAIR (DRILL AND TAP)

Page 4 of 7 NOTE:

When determining drill location, refer to a controlled copy of a cross-sectional drawing for the valve to be repaired.

The location on the valve where injection valves will be installed may be at the bonnet spilt, or below the bonnet split depending on the design of the valve. Valves in which the bonnet protrudes in to the valve body will have a recessed gasket which may require injection valve installation below the bonnet split.

2. DETERMINE drill location on valve body as specified on applicable valve worksheet.

3, WHEN the HPPG assembly will be used, THEN INSTALL the HPPG assembly.

VALVE BODY WITHOUT RECESS WORKSHEET Valve EIN #

Fll Valve Manufacturer:

Valve Size:

Dimension "A":

Total number of injection valves to be installed:

Location "B"is the drill location

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 60 of 69 ATTACHMENT 12 VALVE BONNET GASKET REPAIR (DRILL AND TAP)

Page 5 of 7 VALVE BODY WITH RECESS WORKSHEET Valve EIN #

Valve Manufacturer:

Valve Size:

Dimension ."A" Dimension "B" Total number of injection valves to be installed:

E a aaw*

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 61 of 69 ATTACHMENT 12 VALVE BONNET GASKET REPAIR (DRILL AND TAP)

Page 6 of 7

4. LOCATE AND CENTER PUNCH valve body at location(s) specified by one of the preceding Worksheets.
5. SELECT appropriate size pilot drill bit for injection valve size to be installed from Drill & Tap Sequence Chart (step 4.2.1).
6. DRILL valve body, using a positive drill stop to prevent drilling completely through valve body wall.
7. TAP valve body using drill and tap sequence chart.

NOTE:

The appropriate size injection valve is dependant on which Team Industrial Services chart was used to drill the hole.

8. INSTALL injection valve into valve body AND TIGHTEN securely.
9. CLOSE injection valve.
10. DRILL AND TAP additional locations specified, beginning opposite original location.
11. INSTALL AND TIGHTEN injection valves in all drilled and tapped holes.
12. OPEN an injection valve.
13. SELECT appropriate size pilot bit,
14. ENSURE drill stop is set to allow drill through.
15. USING a stop and go motion, AND the injection valve as a drill guide, DRILL through valve body.
16. RETRACT drill AND CLOSE injection valve.
17. REPEAT steps 4.2.4 through 4.2.16 for remaining injection valves.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev- 00600 Page 62 of 69 ATTACHMENT 12 VALVE BONNET GASKET REPAIR (DRILL AND TAP)

Page 7 of 7

18. INSERT hydraulic injection gun into injection valve(s).
19. PUMP sealant with hydraulic injection gun until back pressure is felt.
20. OPEN the injection valve.

CAUTION:

If sealant is believed to have entered the main line the subject valve controls while pumping sealant with hydraulic injection gun, then the leak repair must be stopped and put in a safe condition. The Control Room and Engineering must be contacted and informed of potential foreign material inclusion.

21. PERFORM the following to INJECT sealant:

A. PUMP sealant with hydraulic injection gun until all of the following occurs:

" Back pressure is felt.

" The leak is sealed.

" The sealant compressed.

  • The amount of sealant as determined by Engineering has been installed.

NOTE:

Peening is a method used to reduce the area between two planes. During this type of leak repair, peening is used to reduce or stop sealant extrusion.

B. IF peening has never been performed the valve bonnet and body split, THEN peening may be performed to prevent sealant extrusion.

C. ALLOW adequate cure time for the sealant.

D. REPEAT steps until leak stops.

22. WHEN evaluation is satisfactory, THEN clean job area.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 63 of 69 ATTACHMENT 13 VALVE / LINE KILL - HOT TAP RING I of 5

1. Purpose On-stream injection of sealant in order to stop flow.
2. Equipment And Tools
1. Appropriate size Hot Tap Ring (HTR)
2. Injection Valve(s). ENSURE the need for reduced stem leakage with the following options:
i. Ball valves are the best option. ENSURE the materials of Composition for compatibility with the service, pressure and temperature.

ii. A second option is pre-injecting the injection valve to seal around the shut-off. This may not achieve 100% positive seal, but may.reduce the leakage significantly.

1. SEAL the end of the injection valve. This may be done by installing a DTSP on the end of the valve or threading the injection valve into a drilled and tapped hole prior to performing the Drill Thru.
2. INJECT a compatible sealant into the valve and rotate the shut-off pin.
3. ALLOW the sealant time to cure, NOTE:

If using a ball valve for injection, a pipe plug will be installed into the back of the valve when all injection is completed. Also, the valve handle will be removed when all injection is completed.

3. Drill-Thru Safety Plugs (DTSP) or approved pipe plugs.
4. Sealant
5. Check the applicable grade. Nuclear Grade 0 Commercial Grade
6. Type: Batch #:' (if applicable).
7. Type: __ Batch #: __ (if applicable).
8. Hydraulic Injection Gun.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 64 of 69 ATTACHMENT 13 VALVE / LINE KILL - HOT TAP RING 2 of 5

9. Miscellaneous hand tools (including but not limited to)
i. Hammer ii. Combination Wrenches
10. Appropriate taps, as needed.
11. Air Drill Motor with Air Hose
12. Appropriate size Drill Bits, as needed,
i. The 148" or 3/16" drill bits are commonly used for this procedure.
13. High Pressure Packing Gland (HPPG) assembly, as advised.

NOTE:

A HPPG assembly is advised for:

A. All process leaks other than steam, water and air.

B. AUl leaks with a pressure greater than 650 psig t 44.8 bars C. All leaks with a temperature greater than 6500 F / 3430 C There is one HPPG designed for the 1/8" drill bit and another HPPG designed for the 3/16" drill bit. Ensure the appropriate size HPPG is used for the drill-thru procedure required for the job.

3. Customer to Furnish I. Scaffolding, platform or ladder, as needed.
2. Plant air supply for small tools, as needed.
3. Purge medium, as needed.
4. Necessary work permits and authorizations.
5. Radiation protection and Health-Physics Service, as required for nuclear applications.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 65 of 69 ATTACHMENT 13 VALVE / LINE KILL - HOT TAP RING 3 of 5

4. Pre-Job Review
1. REVIEW job requirements AND PERFORM a job walk down with the customer.
2. VERIFY with the Customer Contact, conditions are as stated on the Integrated Mechanical Work Permit
3. DISCUSS job schedule, timing, and requirements.
i. To perform the job, if scaffolding will need to be erected
1. Height of scaffold
2. Height and shape of deck
3. Two means of egress are required ii. Manpower and/or special requirements
1. The customer will supply fire watch, bottle watch, hole watch, and so forth.

iii. When will the job start; do any functions need to be coordinated with other crafts; is shift work required.

4. Decontamination of equipment, if applicable.
i. Does the customer have a means of decontaminating equipment and tools that may come in contact with chemicals.

ii. If hazardous waste is generated, does the plant have areas for disposal.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT I &2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 66 of 69 ATTACHMENT 13 VALVE I LINE KILL - HOT TAP RING 4 of 5

5. Procedure NOTE:

A plant Job Hazard Analysis (JHA) is acceptable in lieu of the TEAM JHA as long as all points are covered.

1. COMPLETE TEAM Industrial Services Inc. (TISI) Integrated Mechanical Work Permit.
2. ENSURE for the valve to be in the closed position.
3. LOCATE a spot on the shoulder of the valve to install the HTR.
4. INSTALL an injection valve.

NOTE:

The HTR requires injection to seal around the circumference of the pipe.

5. INJECT the HTR, as required, to obtain a seal.
6. ALLOW time for sealant to cure.
7. DRILL through the injection valve into the system.
i. USE a high pressure packing gland, if applicable.
8. RETRACT the drill bit AND CLOSE the injection valve.
9. ATTACH the hydraulic injection gun hose to the injection valve.
10. BEGIN pumping to provide a positive pressure in the hose.
11. OPEN the injection valve AND INJECT sealant UNTIL:

" Backpressure is felt

" The leak is sealed

" A pre-determined amount of sealant has been injected

12. CLOSE the injection valve AND DISCONNECT the hydraulic injection gun hose.
13. REPEAT steps 5.9 through 5.12 at all injection port locations, as applicable.
14. VERIFY the leak has stopped.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 67 of 69 ATTACHMENT 13 VALVE / LINE KILL - HOT TAP RING 5 of 5 NOTE:

It is recommended that an evaluation be made of the location(s) of the existing injection valve(s), if the leak continues after completing this procedure,

15. ALLOW the sealant time to cure AND REPEAT Steps 5.9 through 5.13 in the same sequence utilized on the first sealant injection.
16. PLUG the back of the injection valve(s) with a DTSP or a plant approved plug(s), if applicable.
17. CLEAN work area.
18. COMPLETE Attachment 8, Post Job Leak Repair Data Sheet.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 68 of 69 ATTACHMENT 14 SEALANT PUMPING PROCEDURE Page 1 of 2 1, PURPOSE Establish injection procedure to be used in conjunction with applicable repair procedure.

2. PRE-JOB REVIEW 2.1. Review job requirements and perform a job walk down.

PROCEDURE 3.1. PERFORM Pre-job brief with all participating personnel.

NOTE:

If more than 1 injection valve is present, the injection valve which will be injected first will be closed and the remaining valves will be opened and used as vents.

If more than 1 injection valve is installed the first injection valve shall be the furthest valve from area with the worst blow.

3.2, IF more than 1 injection valve is installed, THEN ENSURE injection valve which will be injected first is closed.

3.2.1. ENSURE remaining injection valves are open.

3.2.2. ATTACH hydraulic injection gun hose to the closed injection valve.

3.3 IF a single injection valve is installed, THEN ENSURE injection valve is closed.

3.3.1. ATTACH hydraulic injection gun hose to the closed injection valve.

3.4. PUMP hydraulic injection gun UNTIL positive pressure is present in the hose.

ON-LINE LEAK REPAIRS TO VARIOUS UNIT 1 & 2 PRESSURE RETAINING COMPONENTS LR-01, Rev. 00600 Page 69 of 69 ATTACHMENT 14 SEALANT PUMPING PROCEDURE Page 2 of 2 NOTE:

Pumping is to be discontinued if Mainlining is evident.

Bulleted Substeps of Step 3.6 may be marked N/A if condition is not met.

3.5. OPEN the injection valve AND INJECT approved sealant material UNTIL one of the following occurs:

" Back pressure is felt, leak is sealed and sealant is compressed.

OR

  • A predetermined amount of sealant has been injected.

OR

" Mainlining is evident or sealant extrusion is encountered.

3.6. IF at any time while injecting, sealant extrudes or blows out of any open injection valve, THEN CLOSE the valve halfway.

3.7. CLOSE injection valve that has the hydraulic injection gun installed.

3,7.1 REMOVE hydraulic injection gun from injection valve.

NOTE:

Additional injection valves will be injected using the criss cross method.

3.8. IF more than 1 injection valve is installed, THEN CLOSE the next injection valve to be injected.

3.9. IF leak still exists, THEN REPEAT steps 3.2 through 3.7.

3.10. CLEAN work area.

3.11. COMPLETE Attachment 8, Post Job Leak Repair Data Sheet.

ATTACHMENT (2)

REGULATORY COMMITMENT Calvert Cliffs Nuclear Power Plant, LLC December 6, 2013

ATTACHMENT (2)

REGULATORY COMMITMENT The table below lists the action committed to in this submittal. Any other statements in this submittal are provided for information purposes and are not considered to be regulatory commitments.

Regulatory Commitment Date Verify that the installed mechanical clamping device is removed and replaced 4/1/2015 by a permanent code repair or component replacement. The mechanical clamping device will be removed during the Unit 2 refueling outage in 2015 or earlier should a Unit 2 shutdown of sufficient duration occur prior to the 2015 refueling outage.

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