NL-21-006, Relief Request IP3-ISI-RR-16, Proposed Alternative to American Society of Mechanical Engineers Code Case N-513-4 Inspection Requirement

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Relief Request IP3-ISI-RR-16, Proposed Alternative to American Society of Mechanical Engineers Code Case N-513-4 Inspection Requirement
ML21041A509
Person / Time
Site: Indian Point Entergy icon.png
Issue date: 02/10/2021
From: Gaston R
Entergy Nuclear Operations
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
NL-21-006
Download: ML21041A509 (110)
v • d • e


Text

Entergy Nuclear Operations, Inc.

1340 Echelon Parkway Jackson, MS 39213 Tel 601-368-5138 Ron Gaston Director, Nuclear Licensing 10 CFR 50.55a(z)(2)

NL-21-006 February 10, 2021 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

Subject:

Relief Request IP3-ISI-RR-16, Proposed Alternative to American Society of Mechanical Engineers Code Case N-513-4 Inspection Requirement Indian Point Nuclear Generating Unit No. 3 NRC Docket No. 50-286 Renewed Facility Operating License No. DPR-64 In accordance with Title 10 of the Code of Federal Regulations (10 CFR) 50.55a(z)(2), Entergy Nuclear Operations, Inc. (Entergy), requests U.S. Nuclear Regulatory Commission (NRC) approval of Nuclear Generating Unit No. 3 (IP3) Relief Request No. IP3-ISI-RR-16. This relief request proposes a one-time alternative to the acceptance standards of Article IWD-3000 of the American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel (B&PV) Code,Section XI, 2001 Edition through 2003 Addenda for the requirements from IWD-2500 and Table IWD-2500-1 for Examination Category D-B, "All Pressure Retaining Components," Item No.

D2.10.

The proposed alternative provides for a one-time exception to the periodic inspection requirement in ASME Section XI Code Case N-513-4, "Evaluation of Criteria for Temporary Acceptance of Flaws in Moderate Energy Class 2 or 3 Piping,Section XI, Division 1."

Specifically, Entergy proposes to replace the first periodic 90-day flaw growth inspection with a requirement to perform the first inspection within 150 days. This relaxation would extend through the permanent IP3 plant closure date of April 30, 2021.

Performance of the periodic inspection requirement in ASME Section XI Code Case N-513-4 would present unusual difficulties without a compensating increase in quality and safety.

Specifically, the performance of periodic inspections required by Code Case N-513-4 could result in a safety concern for the Nondestructive Examination (NDE) personnel and potentially impact the performance of the NDE equipment. In addition, activities required for performing additional examinations may further degrade the condition of the component such that the periodic inspection cannot be completed. This would result in an unplanned plant shutdown prior to the permanent plant shutdown on April 30, 2021, even though the affected location has significant structural margin beyond that required by the Code Case.



 

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NL-21-006 Relief Request No. IP3-ISI-RR-16

NL-21-006 Page 1 of 8

1. ASME Code Component(s) Affected The affected component is the Class 3 Indian Point Nuclear Generating Unit No. 3 (IP3) Service Water (SW) Line 1093 which provides cooling to the Central Control Room Air Conditioners (CCR ACs) and the Emergency Diesel Generators (EDGs) Lube Oil and Jacket Water heat exchangers. Specifically, the following are the applicable American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel (BPV) Code,Section XI, (Reference 1) examination categories and item numbers affecting the SW pipe. The examination category and item number are from IWD-2500 and Table IWD-2500-1 of the ASME BPV Code,Section XI.

Examination Category Item No.

Description D-B D2.10 All Pressure Retaining Components

2. Applicable Code Edition and Addenda

ASME Code,Section XI, "Rules for Inservice Inspection of Nuclear Power Plant Components,"

Code 2007 Edition with Addenda through 2008.

3. Applicable Code Requirement

Paragraph IWD-2500 of the ASME BPV Code,Section XI, requires that components be examined and pressure tested as specified in Table IWD-2500-1. Table IWD-2500-1 requires that pressure retaining components be pressure tested with a System Leakage Test in accordance with the requirements of IWD-5220, concurrent with a VT-2 visual examination. The acceptance criteria that is provided in IWD-3000 does not allow through-wall leakage or include analytical evaluation criteria for acceptance of through-wall flaws.

ASME Section XI Code Case N-513-4, "Evaluation Criteria for Temporary Acceptance of Flaws in Moderate Energy Class 2 or 3 Piping," (Reference 2) provides analytical evaluation rules for temporary acceptance of flaws, including through-wall flaws in moderate energy Class 2 and 3 piping. Code Case N-513-4 has been unconditionally approved by the NRC in Regulatory Guide 1.147, Revision 19 and endorsed in 10 CFR 50.55a(a)(3).

Paragraph 2(e) of the code case requires performance of periodic inspections at not more than 90-day intervals to verify flaw growth analysis predictions, when a flaw growth analysis was performed. Since Entergy Nuclear Operations, Inc. (Entergy) performed a flaw growth analysis, in accordance with the requirements of sections 2(e) and 3.6 of Code Case N-513-4, a 90-day periodic inspection frequency has been implemented.

4. Reason for Request

Relief is being requested to extend the first and only periodic inspection required by ASME Code Case N-513-4, paragraph 2(e) from 90 days to 150 days. This one-time relaxation would extend through the plant closure date of April 30, 2021 and would eliminate the need to remove the currently installed leak mitigation clamp for the sole purpose of performing the inspection.

NL-21-006 Page 2 of 8 The affected pipe is a 10-inch Service Water line which was originally designed in accordance with the requirements of the 1967 Edition of the ANSI B31.1 Code. This line supplies river cooling water to the CCR AC and the three EDGs jacket and lube oil heat exchangers. The leak was originally estimated to be approximately 15 gallons per minute (GPM) through a 3/8-inch through-wall hole located within an approximate 1.375 inch by 3 inch thinned area. The pipe wall thinning is a result of outside diameter (OD)-initiated corrosion caused by an adjacent vacuum breaker valve with a history of leakage, resulting in intermittent wetting of the OD surface of the SW pipe.

The leakage that caused the external corrosion has since been corrected by diverting it away from the surface of the SW pipe.

At the time that the original leak was discovered (i.e. December 10, 2020), the degraded area was successfully characterized through Ultrasonic Testing (UT) and physical measurements, as required by Code Case N-513-4, paragraph 2(a). However, completion of the inspection was challenged due to the amount of leakage, the condition of the surface of the pipe, and the proximity of the pipe to the wall penetration, the floor and the adjacent SW pipe. Once the characterization of the degraded area was completed, the area was encapsulated with a leak mitigation clamp to minimize the leakage through the hole.

Entergy performed a flaw growth analysis of the degraded Class 3 SW piping in accordance with the requirements of Code Case N-513-4 and is documented in Enclosure 2. A bounding finite element analysis (FEA) of the degraded area was performed and is documented in Enclosure 3.

The original inspection identified the degraded area as two adjacent areas with reduced wall thickness. The first area was approximately 2 inches in the circumferential direction and approximately 1.375 inches in the axial direction. The second adjacent thinned area was measured at approximately 1 inch in both the axial and the circumferential directions. Although both of these degraded areas experienced wall thinning, there was still significant remaining thickness in both areas, with the exception of the 3/8 inch diameter leaking hole.

In the FEA analysis, these two degraded areas were modeled as two through-wall holes with a total dimension of 4.4 inches in the circumferential direction and 3 inches in the axial direction. In addition, a corrosion rate of 0.012 inch per year that was based on IP3 operating experience was assumed to occur through the remainder of the plant operating life. The analysis of these two bounding flaws resulted in a limiting stress ratio (i.e., the ratio of the calculated stress over the allowable stress) of 69%. These results demonstrated that the affected pipe section would remain structurally acceptable for at least an additional five months of unit operation (i.e., through at least May 9, 2021).

As documented in Reference 3, the IP3 average corrosion rate of 0.012 inches per year is a reference value used in structural calculations to estimate the expected remaining life of carbon steel material exposed to raw Hudson River water. The rate is based on carbon steel material for which the concrete lining inside the pipe provides no protection from the raw water in the pipe. The value of 0.012 inches per year was determined by assuming that leaks developed over the life of the plant (IP3 began operation in 1975). The nominal 0.375 inch wall thickness common to much of the large-bore service water piping was divided by the years of plant operation to yield an estimated rate of 0.012 inches per year. Even though the above corrosion rate was established from internal corrosion data and the degradation discussed in this relief request is external corrosion, this value is still applicable because the estimated corrosion during the period of this relief request is a result of carbon steel piping material exposed to raw Hudson River water.

NL-21-006 Page 3 of 8 Since the corrosion rate of 0.012 inches per year is a system average and local conditions can result in variability in this rate, as discussed above, a bounding flaw evaluation was performed to ensure that additional margin exists above that required by Code Case N-513-4, as well as ensure that corrosion rate variability resulting from local environmental conditions does not result in structural margins lower than those required by the Code Case.

Entergy also evaluated the impact of leakage from the through-wall pipe flaw on system operability and plant flooding. A hydraulic analysis of the SW system indicated that the system would remain capable of performing its intended cooling function under limiting design bases conditions with a leak up to 200 GPM. At the normal system operating conditions, a hole size of approximately 0.85 inches in diameter would be required to yield a 200 GPM leak rate. Even though this hole size is significantly smaller than the limiting structural hole size, the daily leakage monitoring will allow for changes in the leak rate to be identified and corrective actions to be implemented prior to approaching the 200 GPM analyzed limit. The approximate 1.5 GPM of leakage after installing a leak mitigating clamp and the estimated 15 GPM of leakage prior to installing the device are both significantly less than the calculated 200 GPM leakage limit. This assures significant margin between the estimated leakage and the amount of leakage which could impact the ability of the system to perform its design basis functions. The effects of flooding and system spray were also evaluated. Entergy concluded that based on the location of the leak (i.e., no sensitive equipment in the area) and the available floor drainage, that neither spray nor flooding will adversely impact the ability of the SW system to perform its design basis function.

Entergy assesses leakage in the degraded SW piping through daily operator rounds to ensure compliance with paragraph 2(f) of Code Case N-513-4. These operator rounds assess both the leak rate and the spray pattern around the leak mitigation clamp. These assessments ensure that the observed leakage remains low and the rate of change is stable. If a visible step change in leakage is identified, the change is documented in the corrective action program and evaluated to ensure that it is not an indication of unstable defect growth. Corrective actions will be implemented prior to approaching the structural limits of the Code Case or the system flow requirements.

Periodic Inspection Challenges As noted above, the degraded area was originally characterized by UT and physical measurements, in accordance with the requirements of Code Case N-513-4. However, in order to perform the UT inspections, surface preparation was required due to the condition of the outside surface of the pipe. Since the installation of the leakage mitigation clamp results in the outside surface of the pipe remaining in contact with the river water, additional surface corrosion has likely occurred.

Entergy anticipates that removal of the existing leak mitigation clamp and performance of the 90-day periodic inspection will present challenges, which include:

(1)

Because the surface corrosion resulted in an uneven OD pipe surface, surface preparation was required during the original (i.e., December 2020) characterization of the degraded area. Since the OD surface of the pipe has been fully encapsulated by the leak mitigation clamp since December 2020, additional surface preparation by mechanical means will likely be required to restore the OD of the pipe to an inspectable condition. The additional surface preparation could result in increased leakage, thereby increasing the difficulty of the

NL-21-006 Page 4 of 8 inspection. In addition, increased leakage is expected (i.e., continued pipe corrosion due to service water under the clamp and surface preparation effects), increasing the probability that a unit shutdown would be required to allow work on the correction of the leakage.

(2)

During the original inspection, the leak rate was estimated to be approximately 15 GPM through the 3/8-inch hole. Since this leakage was originating from the area to be inspected, measures had to be implemented to reduce spraying on the Nondestructive Examination (NDE) personnel as well as on the NDE equipment. In that the leakage is likely to have increased since the original inspection, Entergy expects that successful performance of the periodic inspection will be even more challenged.

(3)

Since the temperature of the water has decreased from approximately 50 degrees Fahrenheit (ºF) during the original examination to approximately 34ºF at the current time (i.e., February 9, 2021), the anticipated higher leakage and lower temperatures could present a potential safety concern for the NDE personnel, as well as potentially impact the performance of the NDE equipment.

(4)

The degraded area from where the leakage is originating is located at the bottom of the horizontal pipe, approximately 6 inches from the floor, adjacent to the wall which the pipe penetrates (see Figure 1 below). In addition, there is another SW pipe in close proximity to line 1093 (see Figure 2 below) resulting in limited accessibility to the inspection area.

These accessibility constraints, coupled with higher leakage and colder river water, will increase the degree of difficulty of the inspection.

NL-21-006 Page 5 of 8 Figure 1

NL-21-006 Page 6 of 8 Figure 2

5. Proposed Alternative and Basis for Use

Section 10 CFR 50.55a(z) "Alternatives to codes and standards requirements" states:

Alternatives to the requirements of paragraphs (b) through (h) of this section or portions thereof may be used when authorized by the Director, Office of Nuclear Reactor Regulation. A proposed alternative must be submitted and authorized prior to implementation. The applicant or licensee must demonstrate that:

(1)

Acceptable level of quality and safety. The proposed alternative would provide an acceptable level of quality and safety; or (2)

Hardship without a compensating increase in quality and safety. Compliance with the specified requirements of this section would result in hardship or unusual difficulty without a compensating increase in the level of quality and safety.

The purpose of this submittal is to request relief from the requirements of ASME Code Case N-513-4. Specifically, paragraph 2(e) of the Code Case requires that periodic inspections be performed at a frequency not to exceed 90 days. The 90-day periodic inspection frequency, rather than the 30-day frequency, is applicable since Entergy performed a flaw growth analysis, in accordance with the Code Case. Entergy is proposing a one-time relaxation of this requirement to allow the first periodic inspection to be performed no later than 150 days from the time of discovery (i.e., December 10, 2020). This extension would allow IP3 to continue to operate until its permanent cessation of operations, which is currently scheduled to be April 30, 2021, without the additional periodic inspections beyond the daily operator rounds currently being performed.

NL-21-006 Page 7 of 8 This request is being proposed under paragraph 10CFR50.55a(z)(2). Performance of the periodic inspection requirement in ASME Section XI Code Case N-513-4 would present unusual difficulties without a compensating increase in quality and safety. Specifically, the performance of periodic inspections required by Code Case N-513-4 could result in a safety concern for the NDE personnel and potentially impact the performance of the NDE equipment.

In addition, activities required for performing additional examinations may further degrade the condition of the component such that the periodic inspection cannot be completed. This would result in an unplanned plant shutdown prior to the permanent plant shutdown on April 30, 2021, even though the affected location has significant structural margin beyond that required by the Code Case.

Entergy believes that a one-time extension of the first periodic inspection from 90 days to 150 days is acceptable and does not result in a decrease in the level of quality and safety, based on the following:

(1)

The periodic inspections required by the Code Case have no impact on the structural capability of the pipe but are intended to confirm the accuracy of the assumptions and inputs used in the Code Case evaluations. Since there is significant margin between the measured and the allowable flaw sizes, the additional 60 days requested beyond the ASME Code Case N-513-4 required due date is considered acceptable as structural integrity of the pipe will still be maintained.

(2)

Since the applied stresses resulting from the normal operating and design bases loads are low in the affected area, there is significant margin between the Code Case N-513-4 calculated allowable flaw sizes and the amount of degradation measured during the original inspection, as discussed in Section 4 above.

(3)

Calculations performed in accordance with section 3.2, "Nonplanar Flaws in Straight Pipe," from Code Case N-513-4 have demonstrated that the degraded area will remain within the structural limits provided in the Code Case beyond the date for permanent cessation of IP3 operations (i.e., April 30, 2021, which is within the 150-day period requested). This is based on the FEA analysis which evaluated a 4.4 inch circumferential by 3 inch axial hole, which bounds the as-measured thinning of 3 inches in the circumferential direction by 1.375 inches in the axial direction. The resultant stress was 69% of the allowable stress.

(4)

Since the degradation mechanism is on the OD of the pipe, it was accurately characterized during the previous inspection and is well understood. Based on the UT results and past internal inspections of the pipe, there is no evidence of any active internal degradation of the surrounding area.

(5)

The affected location is being monitored by daily operator rounds, as required by Code Case N-513-4. Thus far, this monitoring has indicated no discernable change in the leakage around the clamp.

(6)

The leak is located in the EDG valve room below the floor grating, which is treated as a confined spaced. There is no sensitive equipment in the vicinity of the leak which could be impacted by the spray.

NL-21-006 Page 8 of 8 (7)

A hydraulic analysis of the system indicated that the SW system would remain capable of performing its intended cooling function under limiting design bases conditions with a leak up to 200 GPM. This assures significant margin between the original leak and the maximum expected leak if the current leak mitigation clamp were to fail.

(8)

A flooding evaluation was also performed for the EDG building where the leak is located. A review of the available drainage in the location of the leak indicated that the capacity of the drainage system far exceeds a 200 GPM postulated leak and therefore flooding of the area as a result of the SW leak is not a concern, relative to the ability of the system to perform its intended design basis functions.

6. Duration of Proposed Alternative

This request is applicable to Entergys ISI program for the IP3 fourth 10-year interval, which is currently scheduled to extend through April 30, 2021.

7. References
1. ASME Boiler and Pressure Vessel Code,Section XI, 2007 Edition through 2008 Addenda, American Society of Mechanical Engineers, New York
2. ASME Code Case N-513-4, "Evaluation Criteria for Temporary Acceptance of Flaws in Moderate Energy Class 2 and 3 Piping"
3. IP3 Program Document SEP-SW-IPC-001, "NRC Service Water Program"

NL-21-006 IP3 Calculation No. IP-CALC-20-00031 Code Case N-513-4 Evaluation of Line 1093 in EDG Valve Room Upstream of Valve SWN-30 December 11, 2020

NUCLEAR MANAGEMENT MANUAL QUALITY RELATED EN-DC-126 REV. 9 REFERENCE USE Engineering Calculation Process IP-CALC-20-00031 Rev. 0 Page 1 of 7 EN-DC-126 R009 ATTACHMENT 9.2 ENGINEERING CALCULATION COVER PAGE ANO-1 ANO-2 GGNS IP-2 IP-3 PLP BRP RBS W3 NP-GGNS-3 NP-RBS-3 CALCULATION COVER PAGE (1) EC # 88770 Page 1 of 55 (3) Design Basis Calc.

YES NO (4)

CALCULATION EC Markup (5 ) Calculation No: IP-CALC-20-00031 (6) Revision: 0 (7)

Title:

CODE CASE N-513-4 EVALUATION OF LINE 1093 IN EDG VALVE ROOM UPSTREAM OF VALVE SWN-30 (8) Editorial YES NO (9) System(s): SW (10) Review Org (Department):

EFIN (11) Safety Class:

Safety / Quality Related Augmented Quality Program Non-Safety Related (12) Component/Equipment/Structure Type/Number:

LINE 1093 (13) Document Type: CALC (14) Keywords (Description/Topical Codes):

Code 513-4 Line 1093 REVIEWS (15) Name/Signature/Date See Attachment A for signatures LPI Consulting (16) Name/Signature/Date G. Bhalla (17) Name/Signature/Date J. Skonieczny Responsible Engineer Design Verifier Supervisor/Approval Reviewer Comments Attached Comments Attached Digitally signed by John Skonieczny DN: cn=John Skonieczny, c=US, o=Entergy, ou=Design Engineering -

Civil, email=jskonie@entergy.com Reason: I have reviewed this document Date: 2020.12.11 17:55:21 -05'00' Gopal Bhalla Digitally signed by Gopal Bhalla Date: 2020.12.11 18:36:12 -05'00' I

--===-Entergy

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NUCLEAR MANAGEMENT MANUAL QUALITY RELATED EN-DC-126 REV. 9 REFERENCE USE Engineering Calculation Process IP-CALC-20-00031 Rev. 0 Page 2 of 7 EN-DC-126 R009 ATTACHMENT 9.3 CALCULATION REFERENCE SHEET CALCULATION REFERENCE SHEET CALCULATION NO: IP-CALC-20-00031 REVISION: 0 I. EC Markups Incorporated (N/A to NP calculations)

1. NA 2.

3.

4.

5.

II. Relationships:

Sht Rev Input Doc Output Doc Impact Y/N Tracking No.

1. CR-IP3-2020-3156

N NA

2. EC 88766

x N

NA 3.

4.

5.

III.

CROSS

REFERENCES:

1. EC 88766
2. Drawing 9321-F-27223
3. Drawing ISI-27223
4. Specification MS-TS-027
5. UT Report IP-UT-20-00038 IV.

SOFTWARE USED:

Title:

NA Version/Release:

NA Disk/CD No. NA V.

DISK/CDS INCLUDED:

Title:

NA Version/Release:

NA Disk/CD No. NA VI.

OTHER CHANGES:

--===-Entergy

NUCLEAR MANAGEMENT MANUAL QUALITY RELATED EN-DC-126 REV. 9 REFERENCE USE Engineering Calculation Process IP-CALC-20-00031 Rev. 0 Page 3 of 7 EN-DC-126 R009 ATTACHMENT 9.4 RECORD OF REVISION Revision Record of Revision 0

Initial issue.

I II

--===-Entergy I

1 I

1 1

I 1

-I

-1

NUCLEAR MANAGEMENT MANUAL QUALITY RELATED EN-DC-126 REV. 9 REFERENCE USE Engineering Calculation Process IP-CALC-20-00031 Rev. 0 Page 4 of 7 EN-DC-126 R009 TABLE OF CONTENTS Section Page No.

1. Cover Page 1
2. Reference Sheet 2
3. Record of Revisions 3
4. Table of Contents 4
5. Calculation Section 5

5.1 Background

5 5.2 Purpose 5

5.3 Method of Analysis 5

5.4 Assumptions 5

5.5 Design Input 5

5.6 References 6

5.7 Evaluation 6

5.8 Results/Conclusions 6

Attachment A -

LPI Calculation LA201741-C-001 7 ( 48 Pages)

Total Number of Pages 55

--===-Entergy

NUCLEAR MANAGEMENT MANUAL QUALITY RELATED EN-DC-126 REV. 9 REFERENCE USE Engineering Calculation Process IP-CALC-20-00031 Rev. 0 Page 5 of 7 EN-DC-126 R009 CALCULATION

5.1 Background

A through wall leak was found during operators rounds in Unit 3 EDG valve room in Line 1093 upstream of valv'SWN-30 (Ref CR IP-2020-03156). The Line 1093 is aligned as non-essential header. The pipe material is ASTM A53 Gr B, Sch 40 with cement lining per Piping specification TS-MS-027. The leakage was identified where external corrosion was found in the past. Structural operability evaluation is required.

5.2 Purpose The purpose of this calculation is to determine the allowable through wall flaw size per ASME CC N-513-4. If the actual flaw including the leak is less than the allowable flaw length, then the pipe will be structurally adequate and operable. Also minimum wall thickness will be determined for the area that show external corrosion.

5.3 Method of Analysis An evaluation of through wall leak is performed in accordance with requirements of ASME Code Case N-513-4. This is based on UT data IP-UT-20-2018.

5.4 Assumptions See LPI Evaluation LA201741-C-001 5.5 Design Input

1. Piping Specification TS-MS-027
2. USAS B31.1, Power Piping Code, 1967 and 1973
3. Drawing 9321-F-27223
4. UT Report IP-UT-20-038

--===-Entergy

NUCLEAR MANAGEMENT MANUAL QUALITY RELATED EN-DC-126 REV. 9 REFERENCE USE Engineering Calculation Process IP-CALC-20-00031 Rev. 0 Page 6 of 7 EN-DC-126 R009 5.6 References See LPI Evaluation LA201741-C-001 5.7 Evaluation See Attachment A - LPI Evaluation LA201741-C-001 5.8 Result/Conclusion/Margin Analysis See Summary and conclusions in LPI report LA2017741-C-001

--===-Entergy

NUCLEAR MANAGEMENT MANUAL QUALITY RELATED EN-DC-126 REV. 9 REFERENCE USE Engineering Calculation Process IP-CALC-20-00031 Rev. 0 Page 7 of 7 EN-DC-126 R009 IP-CALC-20-00031 Rev. 0 ATTACHMENT A LPI Report: LA201741-C-001

--===-Entergy





















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IP-CALC-19-00002 Rev. 0 Wall Thinninv Evaluallon BaHd an Uniformly Thinned Section

1. Delgn Paramelen (80,uld Yllues.,. IIIOUI)

D.,: Outside Dilmlllllr, (In)

'- : Nominal TIKkneu, (in)

Matenal P : Design Presure, (psi)

T : Design Temperature, ("F)

S... : A le Stressat Design TemperalUre, (psi)

(See App. A ol 831.1)

SA : Thennal Ellpanslon Allowable Streas, (psi)

A. An addttiorlal thickness per Seehon 104, I ol B3I.I, (in)

2. Slructural Evaluatlon L Miran<m Thlcknns for Hoop StreN :

1,.,. P"D,1(2(S,,+.4'P)) +A, (in)

b. Mirwm.m TNcknNS IOr Allllll Streu.

la Iha lhennel 1,cp,enslon Slreu required to be fN

!eel?

( No lo, lo?. 0.75'"- end cyr:181 s 150: Yu lof Dlh!irv.ille) 14.. : Allowable,_ lnc:reue rac.ot for Normal Condrton K..,,. : Allov.abte Slrffl increue lac:IOr fot Upset Coid, loo

~

AloW8llle atsesa lnct lllcto1 lcf E~y Con Ion y Allowable_, lncreae IIICID< to, C~-597 Original P.,i,,g Suasaas S.... Notmal Ca-dtlan s11.,. (pal)

S,. Upnt Con<libOn Sitefl. {psi)

~ : Eme,gancy Conc:lltiOn SlreH, (pal Sn.. Thtrmel EJ<pen$,on SIIHt. (p I Lei r' I

  • stress lntens llca1ion lactor

,* = S IF ol thinned secuon

/I.

llZ' * (D0 * * (Do*21,,..J' YID.' * (D0*21".,.)'J Allowlble S NI

  • Allial S1rass ?. 0 Normal condllllons:

fl(,..,, ' S,. * ( P'0J4.. * + (l"l)"(S..,.

  • P"0,14t..,,J'(Z/Z'J) ?. 0 Upset condtlona:

,-Kui,.*S** [ P'OJ..

+ ('M'(S..,

  • P'DJ

)'iZ/Z'll?. 0 Emergency conditions. 'l"~*S,. * [ P'0,141"

+ (rll)'(St..

  • P 00,l4'-l'(ZIZ°)J?. 0 Normal and Th*. E.,ponsion con one; rtS. + $.J
  • I P'OJ~t"..., + ifhl"(S,.,,
  • P-0,l*t,.
  • S,..r(ZIZ1) ?. 0 C Minimum Required ~

f

"'Max ( I.,,,, I"...,, 0 2°1,,..,J. (In);

Lee Ip* r.,.. R,llo.:!. 50, *01<0 ; or> 50, 'Buckling Evalu 110n Required* RJl,,"'

b = *~Dm8la Wldll'I 011

'>ell sec1

&sad on d-,np support t edges, al1ow&bl11 IM.dd ng 11, e BE(l,lblr Acl'UIII COITlpr85SMI 5trlss IS....* POl(l,,,.,Jklo,,,,II'.l(l'A)

AclUII CIOffll)rllAMI 811uu IS...* PO/(t..,,JJ(l,..,.,,r'I'.)(l'A)

Actual oompreahre 8lreA * (S...., - PDl(t..,,JJ(

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3. Th lckne, lor prad l ctd w II lhlnnlng W,, w-rate ~nlyr) batd on IPEC..-pertence r,., minimum wall lhlckn&u lor 2yaars ol uMc1 r_ + 2*1.1 *w, Page 1.~ of CD P*epared by Checked by Line 1093 10.75 0365 A5J Gr8 17100 25660 0.047 (ow temp pipe) no 1323 1762 1980 0.0:,0 1.00 1.00 1.000 10.117 1395 0

7869 27045 0073 74 Eval

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UT Erosion/Corrosion Examination

-=- ntergy Site/Uni Summary No Wortscope IP3 3

10" Line# 1093 BOP Procedure:

Procedure Rev Wol1< Order No

  • CEP-NDE-0505 Outage No.

NIA 5

Report No.

IPl-UT-20-038 00555124-03 Pago.

O' 4

Code:

ANSI B31.1, '67 Ed. * '69 Ad.

CatJltem:

NIA Locabon.

32 MT moat - 5' Drawlng No.:

9321,F-22363 Description* 10" CIS Pipe in diesel valve room Syslem ID Service Wall!r Component ID* 10" U ne # 1093 Thickness/Ola mete 0.365" Um rtaUons:

See Comments & Page 2 Component File No 10" Line 1093 12/20 Size/1.englh.

1 O" Sch 40 Siar! Time:

1608 Finish Time 2352 Callbr:atlon lrlormatlon Partitioning Informal.ion Comoonent Information ca*l>'looo T11e1.-. <***

C.llnllC<l Times I ln,W,ls Cornpc,n,,n1 ~-

Ende,.'Cdfta.,

Component Geometry:

Pipe S1"'1 1604 MAT 0.040" 0.040" Venfy 1715 MAT 0.100" 0.100" Verify.

~

MAT 0.200" 0.199" Verify 2310 MAT 0400" 0.400" M UPSTExl NIA Maln UPST NIA Mein A-1 Q.J Main DNST NIA M. DNST Ext NIA Outside Diameter 10" GndStze:

2" X 2" Max Thickness:

0.438" Min. TI11ckness:

0.125" Nominal Thickness 0.365" Tmin..

0.073" Min. Thicimess Loca~on:

See Pg. 3 Final 2357 MAT 0.500" 0.500" Branch NIA Max. Thickness Locelion.

E-01 Pl!. 4 Branch Ext.

NIA Surface Condition:

As Prepped lnstrumont:

Transducer.

Reference/Simulator Block:

Temp. Tool:

ManulaclUier.

Olympus Manuladun!u Pana metrics Serial No 99-7436 Manufacturer Fluke Model 38DL Plus Senal No.:

1510584(3 Gain 50dB Senal No.:

1003013 Type:

C/S 0.04"-0.5" Serial No..

TH-004-11 Size:

0.312" Freq :

5.0 MHz

  • F Couplant Ref./Slmulator Block Temp.:

55 Model O7908-SM Type:

Sono600Gel Range:

1.00"

  1. ol Elemenls:

Dual Material/Component Temp.:. _4_7 __ "F Belch No..

061 45 Comments/ObstruCllons

  • ParJally paintod1 point l.o point readings, Paint Is rough and surface Irregular, best effort UT.

Results:

Aocepl,t Reject lnlo Tmln = 0.073" per IP-CALC-13-00062. Ref CR.JPl-2020-3156 Examiner Dale Reviewer S,gnalure Date Terpening.

1211012020 NIA Examiner Oate S*te Reviev, Oat NIA Kunz, Troy R Lovol IIL 12J11l2020 Olher Level NIA Data ANII Review Date NIA NIA

~

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ii

-===- ntergy Summary No.; 10* Line # 1093 Elwminur. Terpening, Michael A.

Examiner. NIA U

Olhor. ~Nl..;;.;..A;__ ____________ _

Supplemental Report Report No.:

IPJ-.UT-20-038 Page:

2 of 4

Level:

Ill Reviewer: NIA Dale; leYflt NIA s,10 Review: Kunz, Tro A Level Ill Date: 1211112020 level:

NIA ANII Review; NIA Date:

Comments: Additional Llmlnotlon Information; In 2015 wol1< order 00297484-07 applied Amerlok Scaler & PSX-700 coatings and best effort made to remove coating around lea.k. 0.000" readings on Page 4 @ J-01 & 02 couldn't be acquired.

Sketch or Photo: O:llddelll &!rver_Ve<81lddelll IP3'1Grophle$*PIC1u1es\\SOMCC Wotei\\Llne 1090 p;c 1._,g

~\\ol.'.J.,

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lt.i>tol.. k'?C' U,.\\) l\\M11t1'i. l\\J.

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Supplemental Report

~ Entergy Report No:

Summary No

  • 10" Line # 1093 Examiner. Terpening, Michael A.

IIL Reviewer:

Page:

NIA Examiner N/A NJA Site evl ": Ku~. Troy R LevelllL ~LI J

0th er _N_/A _________ _

Level NIA ANII Review:

/A Comments Pit gage readings In support ot UT readi ngs as UT readings could not be acquired.

Sketch or Plloto: 0 \\lddcal_Sorwir_ Ve18\\lddeal_lP3\\Graphocs*P1Ctu1eslSeMce W terll e 1093 pie 2 jpg

-;,,1!1.1'- 7 {',t u

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1t\\\\1~t-JT ~ Titc WK..

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~ -i;,C:.

l

--- --1 I

,I IPJ-UT-20-038 3

of 4

Date.

Date: 12/1112020 Date*





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COLOR CODED DATA GRID The Survey Name:

10 LINE 1093 12-20 survevoate:

survey oesaip(joo:

PI PE Survey Mode:

Sul'lley Type:

2DGRID Erase Procect1on:

Locabon Note:

lP3 Inspector ID:

NOE Report:

CP3-UT-20-038 Pg 4

of

'I RevleWt?r:

Kin l).l6) 0JSS D-.3$2 P'1941=1 A"9 0.-08 0.396 o...,s 0J9) 0.<<x>

0.374,

l/l/2014 12:00:00 PM THRU COAT Off MAT U'f\\ I TIU< 1tv

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From: McCarty, Edward Troy <emccar1@entergy.com>

Sent: Friday, December 11, 2020 11:42 AM To: Skonieczny, John F <jskonie@entergy.com>

Cc: Haggstrom, Matthew <mhaggst@ente rgy.com>; Meikle, Richard A <RMeikle@entergy.com>

Subject:

The Housekeeping Patch The 7 S 1 damp that shou Id be used for my EC is 14 pounds.. LPII shoulld add that weight to their calc. You cannot take credit for the damp for structural, but adding in the weight is conservative.

This message *s intended for the exclusive use of the intended addressee. If you have receiived this message in error or are not the intended addressee or his or her authorized agent, please notify me immediately by e-mail, discard any paper copies and delete all electronic files of this message.

Paul Bruck From:

Sent:

To:

Cc:

Subject:

John, Sledzinski, Justin <jsledz1@entergy.com>

Thursday, December 10, 2020 3:22 PM Skonieczny, John F; Paul Bruck Vasely, Michael J; Drake, Richard S; Pineda, Juan J; Wittich, Walter RE: Pressure Gauge Near By I just spoke with the watch and the Non-Essential Header pressure is currently 72 psi.

Thanks, Justin





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D Primary Stress Index Stress Flexibility lntensifi*

Characteristic Flexibility cation Description B,

B, h

Factor k Factor i Sketch

~i,.

Welding elbow or 0.4 h - 0.1 s 0.5 1.30 t0 R 1.65 0.9 r _J_

pipe bend (Note (1 )]

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FIG. NC-3673.2(bl-l STRESS INDICES, FLEXIBILITY, AND STRESS INTENSIFICATIO N FACTORS <D0 /tn s 100) [Notes m, m, (l)J









LPI, Inc. Consulting Engineers Advanced Analysis & Fitness for Service Failure & Materials Evaluation Nondestructive Engineering Main Office and Laboratory 304 Hudson Street New York, NY 10013 212.233.2737 Boston Area Office 36 Main Street Amesbury, MA 01913 978.517.3100 Western Regional Office 1165 Jadwin Avenue Richland, WA 99352 509.420.7684 www.lpiny.com LP/ Australia U208, 46-50 Kent Road Mascot, NSW, 2020 02 9693 5500 www.lpinc.com. au

NL-21-006 IP3 Calculation No. IP-CALC-21-00005 Evaluation of Service Water Line 1093, Inspection Point CB-65 Degraded Wall Without Repair, Revision 0 February 2, 2021

Digitally signed by John Skonieczny DN: cn=John Skonieczny, c=US, o=Entergy, ou=Design Engineering -

Civil, email=jskonie@entergy.com Reason: I have reviewed this document Date: 2021.02.02 05:55:51 -05'00' DANO 1 AN02 GGNS IP2

[RI IP 3 PLP BRP RBS W3 NPGGNS 3 NP RBS 3 CALCULATION EC# 89140 Page 1 of 42 COVER PAGE I

Design Basis Cale.

I !RI YES

\\ NO I I !RI CALCULATION EC Markup Calculation No:

IP-CALC-21-00005 I

Revision:

0

Title:

EVALUATION OF SERVICE WATER LINE 1093 Editorial INSPECTION POINT CB-65 DEGRADED WALL WITHOUT REPAIR DYES lR1 NO System(s):

SW Review Org (Department):

Civil/Structural Safety Class:

Component/Equipment/Structure Type/Number:

!RI Safety / Quality Related Line 1093 Augmented Quality Program Non-Safety Related Document Type: CALC Keywords (Description/Topical LA2017 41-C-004 LPI Codes):

REVIEWS Name/Signature/Date Name/Si~~

Date Name/Sig nature/Date LPI Joe Ruch /

  • l/t /4(

John SkoniecznY'.

/

I Design Verifier Responsible Engineer (DV performed by LPI.

Supervisor/ Approval See page 3)

~~~

!RI Reviewer Comments Attached Comments Attached EN-DC-126 R009

IP-CALC-21-00005 Rev. 0 Page 2 of 42 EN-DC-126 R009 CALCULATION REFERENCE SHEET CALCULATION NO: ___IP-CALC-21-00005_______

REVISION: ___0_____

I.

EC Markups Incorporated (N/A to NP calculations)

1.

None

2.
3.
4.
5.

II. Relationships Sht Rev Input Doc Output Doc Impact Y/N Trackin g No.

1. None
2.
3.
4.
5.

III. CROSS

REFERENCES:

None

1.
2.
3.
4.
5.

IV. SOFTWARE USED:

Title:

_ANSYS_____________ Version/Release: _18________

Disk/CD No.__________

V. DISK/CDS INCLUDED: None

Title:

____________________ Version/Release: ___________

Disk/CD No.__________

VI. OTHER CHANGES: None

IP-CALC-21-00005 Rev. 0 Page 3 of 42 EN-DC-126 R009 Revision Record of Revision 0

Initial Issue.





















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LPI, Inc. Consulting Engineers Atl1*,wr.*,t t\\11nlys1, & F,1111,, for St*n*,rt*

Fni/11r,* & Mnta,nls £t*11'11nlio11 N,md,*,trurlrt'l' E.11~1111",*rms Lucius Pitkin - established 1885 36Mam Street

  • Amesoo,y, MA 01913
  • 978.517.3100 New Yorl(

Boston Richland Sydney www.lpiny.com E11s11ri11g the integrity of today's crilicnl i11frnstr11ct11rr for tomorrow's *world.





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1. Design Paramalltfa (Bmed Yllues.,. IIIOUI) 0.,: Outside Dilmlltllr, (In) t_, : Nominal TIKkneu, (in)

Matenal P : Design Preuure, (psi)

T: Design Temperature, ("F)

S... : A ble Stress at Design Tempera1ura. (pal)

(See App. A ol 831.1)

SA : Thennal Ellpanslon Allowable Streu, (psi)

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2. Structural Evaluatlon L Miranwn Thlcknns let Hocp Sires$ :

1,.,. P"D,1[2(S,,+.4'P)) +A, (in)

b. Miliml.ffl TNcknNI IOt AlOIII Sims.

la Iha lhannel *~

Slress required to be fN

!od?

( No lo, lo?. 0.75'"- end cycSal s 150; Yu lor Dlh!ir..iaa)

K,.., : Allewable,_ incn.a J8ciOt for No11'1'111 Condrtui K..,,. ; Allowable Sir SI irctaae lactor f0< Upset Co'<11,oo

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~JOO : Ema,gancy ConcltllOn SlreH, (pal Sn,. Thermal Ellpllll$m Sttess, {I).,)

Le11*

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3. Thlckne, for predicted wall thinning W,. WW rate ~nlyr) ba9td on IPEC pertenca r,., minimum INckneu to, 2yaa111o1..,.;c1 * **- + 2*1.1 *w, Page 1.~ of CD P*epared by Checked by I.Jne 1093 10.75 0365 A53 GrB 17100 25660 0.07 lowttmp p,pa) no 1323 1762 1980 0.030 1.00 1.00 1.000 10.97 1395 0

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UT Erosion/Corrosion Examination

-=- ntergy Sill!/Uni Summary No Wortscope*

IP3 3

10" Line# 1093 BOP Procedure:

Procedure Rev Wol1< Order No.*

CEP-NDE-0505 Outage No.

NIA 5

Report No.

IPl-UT-20-038 00555124-03 Pago.

O' 4

Code:

ANSI B31.1, '67 Ed. * '69 Ad.

CatJltem:

NIA Locabon.

32 MT moat

  • 5' Drawlng No.:

9321,F-22363 Description* 10" CIS Pipe in diesel valve room Syslem ID Service Wall!r Component IQ* 10" Line# 1093 Thickness/Ola mete 0.365" UmrtaUons:

See Comments & Page 2 Component File No 10" Line 1093 12/20 Size/Lenglh.

1 O" Sch 40 Siar! Time:

1608 Finish Time 2352 Callbr:atlon lrlormatlon Partitioning Informal.ion Comoonent Information c:o*i,,a-TIie>.-. (lnl C.lln""1 Times I ln,W,ls Cornpc,n,,,,1 ~-

Ende1>1>'Coffla.,

Component Geometry:

Pipe Ania!

S1"'1 1604 MAT 0.040" 0.040"'

Venfy 1715 MAT 0.100" 0.100" Verify.

~

MAT 0.200" 0.199" Verify 2310 MAT 0400" 0.400" M UPSTExl NIA MalnUPST NIA Mein A-1 Q.J Main DNST NIA M. DNSTExt NIA Outside Diameter 10" GndStze:

2" X 2" Max Th,ckncss:

0.438" Min. Thickness:

0.125" Nominal Thickness 0.365" Tmin..

0.073" Min. Thicimess Loca~on:

See Pg. 3 Final 2357 MAT 0.500" 0.500" Branch NIA Max. Thickness Locelion.

E-01 Pl!. 4 Branch Ext.

NIA Surface Cond11ion.

As Prepped Instrument:

Transducer.

Reference/Simulator Block:

Temp. Tool:

Manulac1urer.

Olympus Manuladun!u Pana metrics Serial No 99-7436 Manufacturer Fluke Model 38DL Plus SenalNo~

1510584(3 Gain 50dB Senal No:

1003013 Type:

C/S 0.04"-0.5" Serial No..

TH-004-11 Size:

0.312" Freq :

5.0 MHz

  • F Couplant Ref./Slmulator Block Temp.:

55 Model O7908-SM Type:

Sono600Gel Range:

1.00"

  1. of Elemenls:

Dual Materiel/Component Temp.: __ 4_7 __ "F Belch No..

06145 Comments/Obwuct1ons*

ParJally palntod1 point t.o point readings, Paint Is rough and surface Irregular, best effort UT.

Results:

Aocepl,t Reject lnlo Tmln = 0.073" per IP-CALC-13-00062. Ref CR.JPl-2020-3156 Examiner Dale Reviewer S,gnalure Date Terpening, 1211012020 NIA Examiner Oate Sile Reviev, Oat NIA Kunz, Troy R Lovol llL 12J11l2020 Olher UIYOI NIA Date ANII Review Date NIA NIA

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ii

~ ntergy Summary No.; 10* Line# 1093 Elr.aminer. Terpening, Michael A.

Examiner. NIA U

Olhor. ~N/..;;.;.A;__ ____________ _

Supplemental Report Report No.:

IPJ-.UT-20-038 Page:

2 or 4

Level:

Ill Reviewer: NIA Dale:

::--:"F-r-f----

Levol NIA s,10 Review: Kunz, Troy A Level Ill Date: 1211 112020 Level:

NIA ANII Review; -'-N/.c..A'-'-------------,,---

Dale: ___

Comments; Additional Limlnatlon Information: In 2015 wot11 order 00297484-07 applied Amerlok Sealer & PSX-700 coatings and best effor1 made to remove coaling around lea.k. 0.000" readings on Page 4 @ J-01 & 02 couldn't be acquired.

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Supplemental Report

-=-Entergy Report No:

Summary No 10" Line # 1093 Examiner. Terpening, Michael A.

Ill Reviewer:

Page:

NIA Examiner NIA NJA Sito 0111,i; Ku~. Troy R Level Ill ~{../

I 0th er _N_/_A ________ _

Level NIA ANII R eview:

/A Comments Pit gage readings In support ot UT readi ngs as UT readings could not be acquired.

Sketch or Plloto: O llddaal_Sorvcr_ Ve1811ddeal_lP3\\Grapl11cs-P1Ctu1es\\SeMce W terll e 1093 pie 2 jpg L. (hit.,.b ~

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IPJ-UT-20--038 3

of 4

Dale.

Date: 1211112020 Date*





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COLOR CODED DATA GRID The Survey Name:

10 LINE 1093 12-20 survevoate:

survey Desaiption:

PI PE Survey Mode:

Survey Type:

2DGRID Erase Prolection:

Locabon Note:

lP3 lnspectw ID:

NOE Report:

[1'3-UT-20-038 Pg 4

of 4

Reviewer:

Kin I lwx I A'9 1).)6) I o.-ce I 0.395 OJSS I o..-,s I O.l9l OJSZ I 0.400 I 0.37*

l'19e 1 l/l/2014 12:00:00 PM THRUCOAT Off MAT fl'f\\ I TRI<

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-_- - Entergy UT Erosion/Corrosion Examination Site/Unit:

IP3 I

3 Procedure:

CEP-NDE-0505 Ou1age No.:

NIA Summary No.:

WELD CB-85 Procedure Rev.:

4 Report No.:

IPl.UT-15-029 Workscope:

G.L 89-13 Worlt Order No.:

21174a4-01 Page:

of 4

Code:

ANSI 831.1, 1967 Ed. -1969 Add.

Cat./llem:

NIA Location:

CB -15' Drawing No.:

9321-F-22443 Oesaiplion: 10" LINE #1093 2' OUT FROM WALL.

System 10:

Service Water Com pone n t 10: Weld CB-65 10" Line# 1093 Thickness/Diameter:

CS I 0.365" Limitations:

ROOUGH SURFACE COND.

Component File No.:

CB-65 Size/length: ____!!' Sch 40 Start n me:

2118 Finish Time:

2200 Callbrallon Information Partitioning lnformallon Comoonent Information calibration Tbidcness (In)

Calibrlllion Times/ Initials c~

8egin/Col/R""'

Elllling/Col'Row Component Geomelry:

PIPE Adual Measured Slarl:

2116 JFP

.040" 0.041" 0.1DD" 0.101" Verify: ~....:!!:!..

0.200" 0.200" Verify: ~...:!!!..

0.400" 0.401" Verify:

~

M. UPSTExl.

NIA NIA MalnUPST.

NIA NIA Main NIA NIA MainONST.

1-A 14-P M. ONSTExl.

NIA NIA Outside Diameter:

10" Grid Size:

2" X2" Max. Thickness:

9

Min. Thickness:

0.172" Nominal Thickness:

0.365" Tmin.:

0.073" Min. Thickness Location:

1-l Final:

2200 JFP 0.500" 0.500" Branch NIA NIA Max. Thickness Location:

4-F Branch ExL NIA N/A Surface Condition:

ROUGH Instrument Transducer:

Reference/Simulator Block:

Tamp. Tool:

Manulaciurer:

Panametrics Model:

37-Dl Plus Serial No.:

101785302 Gain:

51 dB Range:

1.0" Manufacturer.

Panam etrics Serial No.:

99-7436 Manufacturer:

Traceable Serial No.:

674210 Type:

C/S 0.04"-0.5" Serial No.:

QS-1 Size:

0.283" Freq.:

10.0 MHz

' F Couplant:

Model:

0793 Ref./Slmulator Block Temp.:

50.0 Type:

Ultragel Ii

  1. of Elements:

Dual Material/Component Temp.:

49.8 "F Batch No.:

12125 CommentsJObslrudions:

BOTTOM OF THE PIPE IS ROUGH ANO CONTAINS PITTING. SEE PAGE 2 FOR OBSTRUCTIONS.

Results:

Accept lil)

Reject D Info D Tmln

  • 0.073" (1 year service) per IP-CALC-15-00001.

Date I Reviewer Signature Date 3/1112015 LevPNI~*

cc:

Examiner Signature Date Sile Review Si n~

Date NIA

/?1,rE II, C.~iJ$!. I.II 3-I.,s-Other Level NIA Signalure Date ANH Review Signature Dale NIA

~

~

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Supplemental Report

-===- Entergy Report No.:

IP3-UT*15-029 Page:

2 ol 4

Summary No.: _w_e_L_D_C_B-6_s _____ '?"i:;=:---

Examiner. Puterson, JoS11ph j#J Level:

Ill Examiner. NIA Level:

NIA Reviewer:

A.J/lf:

Date:

Site Review:11,gA,qgcsMt tlil~~-~-_,-~---'1-f:"

Other: NIA Level: NIA ANII Review:

Date:

Comments:

THIS REPORT WAS PERFORMED TO OBTAIN READINGS FROM THE FOLLOWING LOCATIONS:

G*1, G-2, G*11, G-13, G-14, H-1, H-2, H-7, H-8, H0 9, H-10, 1-1, 1-2, l-3, 1-4, 1-7, 1*9, 1-10, 1*11, 1*14, J*2, J-8, J*9, J*11, J*12, J-13, J*14, K-1, K-2, L-1, M*1, N*1, P-8, P-9, P*10.

A08, A-9, B-8, 8-9 WERE OBSTRUCTIONS DUE TO A BRANCH CONNECTION. UNABLE TO OBTAIN A READING AT J*14 DUE TO SURFACE CONDITON. p.7 & P.8 WERE OBSTRUCTIONS DUE TO A BRANCH CONNECTION.





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COLOR CODED DATA GRID The Survey Name:

CB65 Survey Date:

Survey Description :

Survey Mode:

Survey Type:

20GRI0 Erase Protection:

Location Note:

Inspector 10: ~~L_.-,. __

,v w.o. 297464-01 PAGE3 OF 4 REVIEWER:

MIii 0.074 0.390 0.25'1 o.m 0.391 0.301 0.110 0.371 0.310 _J 0.175 0.401 O.Jl4 0.227 0.379 0.3<0 0.180 0.J.'11 0.33<4 0.180 Q.380 0.331 0.17()

0.3111 O.Jl2 0.215 0.376 0.324 0.1116 0.375 0.Ji5 0.197 O.Jn 0.Ji5 0.2Sl o..J95 0.350 0.275 0.380 0.349 0.12 0.380 0.Jl9 3/11/2015 4:30:00 PM THICKNESS OFF

~-- _L,L. _

~

Color,..._,

I II NotUll!d -

I 0.365

  • 1*1*111 I 0.119 I 0 UO 0.3 19 I ~

I 0.11'6 0219 r

~

~

Unde,- I Ra# orcoumn ~

Tabl Stilllstlcst 1-I-1-..,_

E-,_

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-=- Entergy Supplemental Report Summar{ No.: WELD CS-65

~

Examiner. Pelerson, Joseph~:td Examiner: NIA ---------------

Other: WA Comments: SEE LAYOUT OF CB-65 BELOW:

Level:

Ill Level:

NIA Level:

NIA Skelch or Pho1o: I\\Cllenl\\VS\\lddeal Ver 8\\ldcleal_Server\\lDDEA~_IP3\\Graphlcs*Pic1Ures\\Servlce Wale/\\CB-65.JPG Report No.:

IP3-IJT-15-029 Page:

4 of 4

Reviewer:

ttf~ ~

Date: ___

Sile Review: 1'1W,t, CJldAfll ~,l'.£ Dale:.l*l.1.*ff:

ANII Review:

~

Date: ___

I\\Client\\YS\\lddeal Ver 8\\ldcleal_Server\\lDDEAL...IP3\\Graphlcs-Plclures\\Servlce Wate/\\CB-4l5*SKETCH.llf d

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Paul Bruck From:

Sent; To; Cc:

Subject:

John, Sledzinski, Justin <jsledz1@entergy.com>

Thursday, December 10, 2020 3:22 PM Skonieczny, John F; Paul Bruck Vasely, Michael J; Drake, Richard S; Pineda, Juan J; Wittich, Walter RE: Pressure Gauge Near By I just spoke with the watch and the Non-Essential Header pressure is currently 72 psi.

Thanks, Justin





















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