ML20211P803

Requests Approval of Encl Main Steam Piping Evaluation,Per ASME Code,Section Xi,Article IWB-3600 & Relief from Requirements of Article IWB-3610(b) Re Primary Hoop Stress Limits.Analyses Justifying Requests Also Encl.Fee Paid

ML20211P803
Person / Time
Site:	Calvert Cliffs
Issue date:	12/16/1986
From:	Thornton A BALTIMORE GAS & ELECTRIC CO.
To:	Thadani A Office of Nuclear Reactor Regulation
References
NUDOCS 8612190140
Download: ML20211P803 (37)

Text

A BALTIMORE GAS AND ELECTRIC CHARLES CENTER. P.O. BOX 1475. BALTIMORE, MARYLAND 21203 NUCLEAR ENGINEERING SERVICES DEPARTMENT CAlvtRT CUFFS NUCLEAR POWER PLANT LUSOY, MARYLAND 20$$f December 16,1986 U. S. Nuclear Regulatory Commission Office of Nuclear Reactor Regulation Washington, D. C. 20555 ATTENTION:

Mr. Ashok C. Thadani, Director PWR Project Directorate #8 Division of PWR Licensing-B

SUBJECT:

Calvert Cliffs Nuclear Power Plant Unit No.1; Docket No. 50-317 Request for Approval of Main Steam Piping Evaluation per ASME Section XI, IWB-3600 and Relief from IWB-3610(b)

Gentlemem While inspecting main steam piping on Unit i under a voluntary inspection program, we detected wall thicknesses below the minimum wall thickness of the original construction code. We performed two evaluations that justify the operation of Unit i until prior to entering MODE 2 from the next refueling outage (scheduled for Spring 1988). Attachment A summarizes the events and the results of the analyses.

The first analysis (Attachment B) is a linear elastic fracture mechanics analysis based on ASME Section XI, Appendix A and an clastic-plastic / plastic fracture mechanics analysis similar to ASME Section XI Article IWB 3640 (1983 through Winter 1985 Addenda). It is provided for your approval per ASME.iection XI, Article IWB-3600.

The second analysis (Attachments C and D) was performed to demonstrate the primary stress limits are met as required by the 1983 Edition through Summer 1983 Addenda of ASME Section XI, Article IWB-3600. This analysis demonstrates that primary longitudinal stress limits are met but primary hoop stress limits are not, it is provided for your approval and for relief from fully satisfying the primary hoop stress limits for the following reasons:

The piping can withstand HOT STANDBY and all transient conditions.

The request is for a limited period of time. Before entering MODE 2 from the next refueling outage for Unit I we will ensure that the affectedpiping will meet all the applicable requirements of ASME Section XI,1983 Edition through Summer 1983 Addenda, h

There is a very low probability of pipe failure.

o

,y 8612190140 861216 DR ADOCK 0500 7

gg gf,$o.o o

Mr. Ashok C. Thadant December 16,1986 Page 2 Pursuant to 10 CFR 170.21, we are including BG&E Check No. (1908266) in the amount of

$150.00 to the NRC to cover the fee for this request.

Please contact us if you have any questions regarding this matter.

Very truly yours, Ni A. R. Thornton General Supervisor Plant and Project Engineering ART / WPM / dim i

Attachments cc:

D. A. Brune, Esquire J. E. Silberg, Esquire S. A. McNeil, NRC T. Foley, NRC p

t I

s

.--,-,,,-c.

--r.

c..

o Mr. Ashok C. Thadani -

Decernber 16,1986 Page 3 bcc:

R. F. Ash /R. C. L. Olson C. H. Cruse /P. E. Katz

~ R. E. Denton/J. A. Mihalcik R. M. Douglass/T. N. Pritchett Dr. M. Gavrilas/E. I. Bauereis J. R. Lemons /R. P. Heibel W. J. Lippold/A. R. Thornton F. J. Munno R. B. Pond /R. E. Cantrell L. B. Russell /J. T. Carroll R. E. Lapp C. M. Rice R. G. Staker W. R. Horlacher, III W. P. McCaughey, Jr.

B. E. Holian P. E. McGrane M. E. Bowman L. E. Salyards R. R. Allen W. C. Holston B. C. Rudell M. J. Gahan

1 of 4

ATTACHMENT A

SUMMARY

OF EVENTS INSPECTION As part of an extensive non-mandatory program to investigate piping for erosion / corrosion effects, ultrasonic thickness measurements were taken on #12 Steam Generator Main Steam Line (EB-01-1005-05) at the second elbow downstream from the flow restrictor.

Initial readings were taken on a grid spacing of 3" by 3".

This elbow is inside the containment at elevation 61'-0".

The pipe diameter is 34", the material is ASTM A-155, Grade KC70, Class I, and the design minimum wall thickness is 0.95".

Downstream of the field girth butt weld joining the elbow to the horizontal pipe, reduced wall thickness readings were recorded on the bottom side of the pipe.

Readings below 0.95",

to as low as 0.86" (90.5% of min. wall), were found immediately adjacent to the weld in a 1/2" band 24" long.

This is 22.5% of the circumference.

The 1/2" band was defined and confirmed during a second ultrasonic investigation.

The wall thickness for the rest of the pipe examined ranged from 1.00" to 1.12".

POST-INSPECTION The probable cause was grinding of the edge of the pipe to achieve proper fit up for welding during initial construction.

Seamed piping normally is difficult to fit-up and some l

grinding may be required to provide a smooth continuous l

surface between pipe sections.

There is no evidence of erosion or corrosion.

I MSEVENTS.MJG

2 of 4

i

)

POST-INSPICTION (cent'd)

We reviewed the radiograph obtained during plant construction.

The film showed a darker band in the same area as indicated by i

j the ultrasonic testing.

Radiography was repeated on December j

3 and the films showed no significant differences. We believe j

this condition has existed since construction and is essentially in its same shape and size after more than eleven l

years of operation.

Five other locations on the main steam line were ultrasonically tested to determine if similar conditions existed.

Pipe wall thicknesses were all found to be satisfactory.

i Nuclear Engineering Services Department (NESD) was notified of the finding on November 26.

A presentation was made to the i

Plant Operating Safety Review Committee (POSRC) to report the finding and to describe the engineering evaluations that would j

be performed.

6 The NRC Resident Inspector was notified by telephone of the i

condition at 0930 on December 1.

Later that

day, Mr.

McBrearty from Region 1 spoke with our representative from l

Design Engineering.

On December 4, a conference call was held between NRC Region 1 members, NRR, the Resident Inspector, and l

various members of NESD.

On December 3, the POSRC was given a full description of the I

evaluations performed and the recommendation to accept as is.

j POSRC accepted the recommendation.

On December 10, a presentation was made to NRR and on December i

11, a

teleconference was held with NRR to discuss the l

situation, subsequent actions, and reporting requirements.

i 1

MSEVENTS.MJG i

,. - ~. - -, -,.. -.

., - - - -.,, - - ~ ~ -, _,, -

i 3

of 4

FRACTURE MECIANICS AMALYSIS i

NESD pursued the provisions for an alternate analysis, as j

allowed by ASME Code Section XI 1974 Edition with Addenda through Summer

1975, IWB-3600.

A linear elastic fracture mechanics analysis based on Appendix A

and an elastic-plastic / plastic fracture mechanics analysis similar to Article IWB 3640 (1983 through Winter 1985 Addenda) were performed and are provided in Attachment B.

The critical flaw size was determined for the maximum load condition factoring in design bases transients.

Flaw propagation was determined for both a i

24 month period and and of life.

This analysis determined j

that there is an adequate margin of safety consistent with l

ASME Section XI criteria.

I PRIMARY STRESS ANALYSIS A second analysis was performed to determine if the primary stress levels as required by ASME Code Section XI, 198'J 4

Edition with Addenda through Summer 1983, IWB 3610(b) are satisfied (*).

The results were evaluated in light of the l

requirements in the original construction

code, ANSI B31.1-1967.

l As shown in Attachment C,

all primary longitudinal stress levels are met for each load combination.

The primary hoop l

l 1

Our Code of record is the 1974 Edition with Addenda through Summer 1975.

The 1983 Edition with Addenda through Summer l

1983 will be effective April 1, 1987.

I

(

l I

l MSEVENTS.MJG I

4 Cf 4

PRIMARY STRES8 ANALYSIS (cont'd) stress levels do not meet B31.1, Paragraph 104.1.

The analyses as documented in Attachment D

demonstrate the following:

The as found wall thickness of the piping can withstand up to hot standby conditions.

Short term transient capabilities are within the worst case pressure load for all chapter 14 analyses.

There is 21% excess reinforcement available in the surrounding pipe wall to ensure structural integrity of the piping system.

In addition, the maximum dynamic hoop stress based on the pressure surge created by closure of the main turbine stop valves combined with design pressure is within the allowable yield stress.

MSEVENTS.MJG

O ATTACHMENT B ELASTIC PLASTIC FRACTURE MECHANICS ANALYSIS

50'JWJEST BESEARCH INSTITUTE Thin Wall Pipe Integrity Assesac:ent For Calvert Cliffa Unit 1 - A Fracture Evaluation P. E. Nair H. G. Pennick SwSI Project 17-4772-861 Deeec6er 16,1986 Reviewed and Approved by:

fx l

Ge M." BFiggs,MTIreetor Structural and Mechanical Systems 4

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{

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,,,--_--,_y

-.---m---

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Southwest Research Institute Thin Wall Pine Intenrity Assassment Objective:

To determine the long term integrity of the reduced section thickness of the steam pipe based on fracture and/or rupture considerations.

Approach:

The reduced thickness of the pipe is limited to a circumferential segment in the base material near the weld. The reduced thickness pipe is conservatively assumed, for fracture mechanies evaluation purposes, to have a surface connected indi:ation with a depth of average pipe thickness minus the reduced pipe thickness.

In the analysis linear elastic fracture principles consistent with ASME Section XI, appendix A, and fully plastic solutions for cracked piping are used.

g:

1) Maximum anticipated eg ivalent pipe pressure 1693 psi (ftydro test),

2) Pipe inner radius R

=

17 in.

g a

1.08 in, Pipe average thickness f

Pipe mininum thickness s 0.85 in.

f

3) Fipe yield stress 38,300 psi.

=

4) Table I.

Espected Plant cycles over 40 years, i

Assumptions:

1) Maximum internal pipe pressure le 1693 psi.

2) Lower bound on fracture toughness for piping l

l matertal = 100 Esi 6.

I

3) Crack growth is suberitical crackgrowth.

4) Table II plant cycles over next 2 years.

5)

Assu=e all stress is membrane.

AEALYSIS:

Calculate Lenaitudiral Stress PR (1693) (17) g 16930 pai o a

=

=

g 2t 2 (0.85)

This would be the stress used in the pipe evaluation.

Critical Crack Size Calculation Based on Unear Elastic Fracture Metheds (A3ME Section 11 Appendix A) 1 1

2 1

100 2

IC 9.2 in

=-

a :

C

_ 1.1 (16.93) v 1.1 e ir 1

I The average wall thickness is given as 1.08 in, which is less than i

l the calculated critical crack-size or 9 2 in.

This impites that the l

thinelled pipe will leak before it can break.

The through thickness leak can develop only when the thin pipe section reaches limit load conditions.

~

~

Estimation of Recuired Pice Vall Thicirness for ( teit Lead Failure.

An estimation of the pipe wall thicirr.ess required to support the anticipated maatzm Icad of 16.93 Isi of longitudinal strees is given below.

CIRCUMFERDITIAL CRACK 2

2 o

8, w (R -R)

EFRI REPORT NP-1931 P

2 e, 1 (R - (R, - c)2]

=

2 2

=-a w

(R2,,2 + 2R C - C )

{c o

o o

2 2

e, w (2B,C - C )

s

'o 2

= 2R,C - C 2e,r 2

P, k C - 28,C -

=0 2a,w o. R,..

3 (R

I a e R, - R1-e R, a R - Rg + Rg - a j

R, a R, - e f

PR R,.. (R - Rb 2

i 25 1

i k

m

~

e (37.886) (1693) (17)

)

3

{!

=

2 (0.85)

= 2,015,048.9 lbs e, = 38300 psi e a section thickness required to support ler.gitudinal stress of 16,930 pai P 1.723

-(-2R,) *

(-2R,)2 4(1)(,2a,v

)

a:-

2 (1) 1.10 P 36.16 2 1307.55 -

36'.16 1 35.35 a

s a

2 2

a 0.405 in.

This approach is similar to IWB-3640 section II 1983 winter addendum 1985. This addendu:n applies primarily to austenttia piping.

Currently, the Section II Working Group is evaluating carben steel pipes.

Estimate Crack Growth Over West 2 Years See Table II for cycle estimates and stress change, M.726 SECf10NIIAPPENDIIA da 3

= 3.795 a 10 gO (water environment) g AK.726 a Aa = 3 795 a 10~10 3

.. a

u

,1 m.

f

.+

,,'N (f

.y o

e

\\'

I

/

k'

(

l i, LK x as % ha/Q Y[

/

N. 1.65 c

]

Q 0.95 O

See Table III Listing of Algoritir 'Jsed.

v

/

, s, The crack was grown in two, transieM load blocks.

Here ere 50 t,

e total beat up and cooldt.e cychs applied in the first transient load

)

i' block.

Then 50,874 cycles c.r ha, r.d, chahges wereappliad in' the second f

t transient load block.

T're total crackgrowth over both load blocks was 0.00285 inches.

Hence, '

initial orael with a depth of 0.23 in, codh,s r

i grown to a depth of 0.233, in, due' to the application of the two transient lead blocks. The two lodd Waks are tains to represent two '

r y i

years worth of transtant cycles on the subject pipe, i

,i

\\

\\

Hence, the cract'6towth is not significant during this time period.

<1 3

Therefore, failure daring this time period must be through not section yielding or pipe collapse.

Sumary & Conclusiem:

A ' detailed long term structural integrity y,

assessment was performed for the thin section ef' the pipe.

It has been i

determined that a $1pe' thickness of 0.405 Meh n vse13er will be r

required before the pipe osn 'j leak under any anticips.wd accident e

1

/

overload condition.

The futura in'.orvice degradation et thicc ess, based on cyclic fatigue orack y.-Stb calculations, deconstrate nu

,J significant crack growths within a-two 3 car inspectier. ac:ieCle.

End of,

l

)

life (of plant - 40 yers) degradation rs.k es de also' amall.

The I' 8

factors of safety based en linear alastic analysia is large, i.e. >10

/

,t 4

l r

i I

e t

/.

I

4.

and the rupture load is approxicately four times g;reater than the c1xic:.c anticipated,1oid en the pipe,

' s

)

s s

b i.

q,

.- t a

N;,

-i s

REFERiiN;ES

!j

'1) ASME Boiler and Presure Vessel Code,Section II, Appendix 1,1983 2)

V. Kumar, M. D. German, C. F. Shih, 'An Engineering Approach for Elastic-Plastic Fracture Analysis", EPRI Peport WP-1931, July 1981.

3) A5ME Boiler and Pressure Vessel 00de, Secticn II, IW3-3640, 1983 Winter Addendum 1985.

na i

l s

i p.

l l

- v I

l 8

TABI.E I.

Espected Plant Cycles Over 40 Years a.

500 Heat Up and Cool Down Cycles.

b.

15,000 Power Changes 15-100% 9 55/ min 532F - 572.5F 900psig - 850 pais c.

2000 Power Changes 10-905/100-205 Same tecperature & pressure ranges d.

1,000,000 cycles of +/- 6F e.

400 trips frc= 1005 Same temperature & pressure ranges f.

40 cycles of loss of turbine at 100%

Same temperature & pressure ranges g.

40 oycles of loss of reactor coolant flow Sa=e temperature and pressure ranges h,

5 oycles of loss of secondary pressure

TABLE II.

Assu=ed Plant Cycles Over Next Two Years Nazber Strass of Change cycles (ksi)

Transient Cvele 25 16.93 Heat Up cocidewn 750 0.85 Power Changes 155 - 1005 103 0.85 Power changas 10 905/100-20 50,000 0.85

+/- 6 *r 20.0 0.85 Trips from 1005 2.0 0.85 Loss of Turbine i 100%

2.0 0.85 Loss of Reactor Coolant Flow 0.25 3.39 Loss of Secondary Pressure o

TAELE III. Crackgrowth Algorithz rtM= 1. 45 D55=16.93 AI=.23 DE=D55 A=AI G=,95 DDA=0 FOR I = 1 TO 50 D A= (3. 795E-10) * (DE*MM*SCR ( A*3.14159/C) ) ^3. 726 0 A=A + DA

)

O DDA=DDA + DA 0 NEXT O LPRINT "A=

";A,"

DDA= ";DDA 0 0E=.054055 0 FDR'I = 1 TO 50874!

O D A= (3. 795E-10) * (DS*MM*5CR ( A*3.14159/Q) ) ^3. 726 0 A=A + DA O DDA=DA + DDA O NEXT O LPRINT A =

")A,"

DDA= "pDDA 9

O 1

ATTACHMENT C LOAD AND STRESS

SUMMARY

LONGITUDINAL F (pounds), M (foot pounds), Stress (PSI)

LOAD CASE FX FY FZ MX MY MZ THERMAL 4801

-27018

-14716

-258299 122799

-36240 DEAD WEIGHT 175 1568 91 7019 1274 857 SEIS ANC MVT 5356 2722 5559 38948 74574 47724 SEISMIC OBE 1410 869 6680 16476 5251 4006 SEISMIC DBE 2644 1630 12526 30893 9845 7512 STEAM HAMMER

-10300 5465 43050 93493 39690 22850 LOAD CASE STRESS (0.95")

STRESS (0.86")

PRESSURE 8204 9140 THERMAL 4245 4664 DEAD WEIGHT 106 117 SEIS ANC MVT 1429 1570 SEISMIC OBE 261 287 SEISMIC DBE 490 539 STEAM HAMMER 1418 1558 LOAD COMBINATIONS:

O.860" THICKNESS ALLOWABLES NORMAL (PRESSURE = 1000 psig)

B31.1 102.3.2(d) 9257 psi 17,500; 1.0 SE P

+

DW

=

UPSET (PRESSURE = 850 psig)

B31.1 102.2.4 9444 psi 21,000; 1.2 SE P

+

SH

+

DW

=

SECONDARY B31.1 102.3.2 (c) 6234 psi 26,250; 1.5. SE TH

+

SAM

=

FAULTED (PRESSURE = 850 psi)

See " Note" P

+

SSE

+

DW = 8425 psi 30,500; Sy @ 525F Note:

The allowable for the faulted condition is based on Code case 1606 for ASME

III, NC-3 611.1(b) (4 ) (b).

ANSI B31.1-1967 did not provide criteria for the faulted condition.

MSEVENTS.MJG

_ ATTACHMENT D ANALYSIS OF PRIMARY STRESSES (12 Sheets)

REVISION O DESP-6 A3 CALCULATION COVER SHEET Calculation Number // - //

/t'>

Page

/

of /2 A.

SUBJECT:

ll/)/K N H /n / i m /ds!/ f/,p e n s J

B.

LOdINFORMATION:

1. Keyword:

[di//

[/><4

2. System, S-U No.:

,O A41<.'s w.

3. Component:

h en

4. FCR No.:

(([ 8 C.

These engineering calculations have been performed in accordance with established procedures, the accuracy has been assured, and I certify that the above calculation has been performed, reviewed, or approved as noted below.

ORIGINATOR

[

S"E Date fA61'((

REVIEWER N

[o/ _b Date /8'/ N APPROVED Date/

((c, REVISIONS REV.NO DESCRIPTION ORIG. DATE REVIEW DATE APPR. DATE l

t LIST OF EFFECTIVE PAGES l

l PAGE REV PAGE REV 1

0 7

0 2

0 8

0 3

0 9

0 h

0 10 0

5 0

11 0

6 0

12 0

1 h

REV O M-86-10 SH 2 of 12 OBJECTIVE: Main Steam piping spool piece, 1-101-2-EB1-1005-8, has a local area of wall thining just downstream of Field Weld 4 as shown on drawing 1-101-2, Foreign Print 12629A-02. Using the top of the pipe as zero degrees the defect is in an arc within approximately 170-250 degrees. The area is judged to be at least 1/2" wide by 24" long in a circumferential orientation. See attached ultrasonic thickness measurement record (Ref 4). The purpose of this best estimate analysis is to determine the minimum required wall thickness based on normal and anticipated transient operating pressure conditions and thus, to assess the acceptability of the thin wall condition.

GIVEN:

1. The piping design pressure and temperature are 1000 psig and 580F as per M-601(Ref 2). The piping material is ASTM A-155 KCF70 Grade 1 as per M-600(Ref 2).

2.

As per the FSAR Table 4-9 the hot standby temperature is 532F, this corresponds to a saturated pressure of 900 psig. Per the FSAR Section 14.5, Loss of Load, the maximum accident transient pressure is 1095 psia. The other accidents are LOFW (14.6) 1048 psia, Loss of Non Emergency AC (14.10) 1041 psia, Asymmetric Steam Generator (14.12) 1074 psia, SG Tube Rupture (14.15) 1055 psia and Feed Line Break (14.26) 1021 psia.

3.

The actual Certified Material Test Report for this segment of pipe was pulled from the plant history files. A copy is included as page 12. The Code states that the assumed tensile strength is 70,000 psi.

Our material has an actual tensile strength of 71,100 psi. ANSI B31.1-67 (Ref 1), 102.3.1(b), states that the allowable stress is determined by taking 25% of the specified minimum tensile strength at room temperature. I will use 25% of the actual tensile strength for the allowable in this calculation. This will raise our allowable from 17,500 to 17,775 psi.

4. The original ultrasonics measurements were performed on a grid spacing of three inches. The area was rescoped to determine the extent of the area below minimum wall. It was found that an area 1/2" wide from edge of th'e weld fusion line, extending around the circumference from 48-3/4" to 72" (zero inches and degrees is taken as top dead center of the pipe). The reinforcement computation will conservatively assume that the entire three inch grid area is at the thickness shown on the attached Ref 4.

ASSUMPTIONS:

1. The device used to measure the wall thickness was a Sonics Mark 1 with a CRT and Digital Readout. It was calibrated with a step block. Based on a conversation with Dr. R.

Pond, BG&E Principal Metallurgist, the accuracy of these readings is +/- 5 mills. The probe has a 1/4" diameter.

REV O M86-10 SH 3 of 12

2. No erosion / corrosion allowances are included because it is assumed that this condition has been there since initial construction. The basis of this assumption is as follows. (1) The original radiographs were pulled and there was a thin dark line in the vicinity of the defect. Mr. A Reid, BG&E Metal Lab, after looking at the film, felt that there had been misalignment between the elbow and pipe and the welder had ground it out as part of the weld prep. (2) Several other areas were measured in the main steam piping to see if the thin wall condition existed elsewhere. These areas were two elbows in the containment (one in each main steam line), one elbow in the penetration room and two tees in the turbine buiding at the manifold tie-in point. No evidence of thinning was found. (3) Based on industry studies (Ref 7) it is not thought that Erosion / Corrosion occurs in the dry steam environment that this piping is exposed to.

3.

The COMPUTATIONS show that the actual pipe wall thickness can withstand a pressure of 912 psig. The design pressure can not be changed to this value because we can not reset the relief valves to protect that point. The applicable Code, ANSI B31.1, 102.2.4, allows pressure or temperature to exceed the design conditions for short transients as long as the maximum expected pressure does not exceed the following criteria: up to a 15% increase above the allowable stress for 10% of the operating period; up to a 20% increase above the allowable stress for 1% of the operating period. The Operating Period was not defined in the 67 edition of this code. From the 77 edition to the present this term is stipulated as 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

Although the Code does not allow the use of these values to legitimize a pipe wall thickness below the minimum allowed at design pressure, the additional stress created by a specific increase above the design pressure is comparable to that created by a similar pressure increase above the pressure retaining capability of our thinner wall condition. Therefore even though this approach is outside the strict rules of the Code,it provides a means of determining if the pipe can withstand the FSAR transient pressure conditions.

4. When a hole is drilled a in pipe and it exceeds a set amount as designated by the Code', it must be shown that there is adequate reinforcement available to support the weakened area. In this case we have not created a hole in the pipe but we do have an area that does not have the specified pipe wall thickness. I will use this concept to demonstrate that there is adequate excess material in the adjoining pipe wall, weld and fitting to support the " weakened" area.

ANSI B31.1, 104. 3.1 (d) discusses circular branch connections.

Our defect area is a rectangle. Therefore some adaptation of the rules is necessary. This analysis considers reinforcement volumes, while the Code looks at areas. The Code uses areas because it assumes uniform wall thickness. The required reinforcement is 1.07 times the cross section of the area removed; therefore, I will use 1.07 times the missing volume.

REV O M86-10 SH 4 of 12 The Code allows consideration of the area within one diameter of the branch on either side of the centerline of the branch.

Therefore, I will credit extra volume only within half of the width of the segment extending all the way around the segment.

Wall thickness measurements will be used from references 3&4. The weld thickness will be taken from the 180 degree reading as this is closest to the defect area.

REFERENCES:

1.

ANSI B 31.1-67 2.

Document M-600 Piping Class Sheets Document M-601 Piping Class Summary Sheets

3. Weld Examination Record, attached.

4. Ultrasonic Thickness Measurement Record, attached.

5.

BGLE Foreign Print 12629A-02

6. Updated FSAR 7.

EPRI Report NP-3944, April 1985 Erosion / Corrosion METHOD OF ANALYSIS:

Hoop stress computations will be performed in accordance with ANSI B31.1, 104.1.2, formulas 3&4. The below formulas are derived from the Code formulas, assuming A=0 as allowed by Table 104.1.2(a)1 and assumption number 2.

t(min)=(P Do)/(2 (SE+P Y))

P=(2 SE t(min))/(Do-2 Y t(min))

t(min), minimum wall thickness, inches P,

design pressure, psig Do, outside diameter, inches SE, max allowable stress in material, psi, normally Appendix A-2 Y,

coefficient, 0.4, Table 104.1.2(a)2.

1.

Determine the actual required pipe wall thickness, based on 1000 psig 2.

Determine the actual 0110wab.le pressure the existing pipe thickness surrounding the defect area can handle.

3. Using Assumption three', determine the transient pressure capabilities of the pipe.

4.

Determine the availability of excess reinforcement in the surrounding pipe wall and weld.

COMPUTATIONS:

1. Required Wall Thickness t (min) = (1000psig) ( 3 41nches) /2 (17500 psi +. 4 (1000psig) )

t(min)=0.950" NOTE: For the computations #2&3 I will use the higher allowable stress from the actual tensile data =17,775 psi. The accuracy of the ultrasonic thickness detector, 5 mills, will be subtracted from all readings for the following computations.

REV O M86-10 SH 5 of 12 2.

Actual Allowable Pressure P= ( 2 ) (17775 psi) ( 0. 8551nches) / ( 341nches- ( 2 ) (. 4 ) ( 0. 8551nches) )

P=912psig 3.

Transient Pressure Capabilities

-10% of the operating period P= (2) (1.15) (17775) (0. 855) / (34-(2 ) (. 4 ) (. 855) )

P=1049psig

-1% of the operating period P= (2 ) (1. 20) (17775) (0. 855) / (34-(2 ) (. 4 ) (. 855) )

P=1094psig Max FSAR transient = 1095 psia-14.7=1080.3psig

4. Excess Reinforcement Available See Sketch on Ref 4.

Note:

It is not completely certain that the "x" coordinates

-for the elbow match the piping coordinates.

Therefore fitting thickness was taken as the eight lowest readings.

(1.06+1.08+6(1.20))/8=1.168-0.005=1.163" The area within the solid red line is that which is below minimum wall. The area which-is within the dashed boxes is that which will be used for reinforcement. The reinforcement volume is divided into four pr.rts.

-Area of below minimum wall: 21"*3"=63sq.in.

-Volume required: 0.950"*63sq.in=59.85cu.in.

-Average thickness in below minimum wall area:

(5(.855)+(.915)+(.895))/7=.8691n

-Volume available in reduced wall area: 0.869*63=54.765cu.in.

-Volume to be made up: 59.85-54.765=5.085cu.in.

-Increased by 7%= 1.07*5.085=5.441cu.in.

Volumes available for reinforcement Volume 1 Area =24"*l.5"=36sq.in.

Average Thickness =(3(1.075)+2(1.055)+3(1.035))/8=1.055" Excess Thickness =1.055-0.950=0.105" Reinforcement Volume =36*0.105=3.78sq.in.

Volume 2 WELD Area =24"*l.375"=33sq.in.

Excess Thickness =0.995-0.950=0.045" Reinforcement Volume =33*0.045=1.485cu.in.

Volume 2 FITTING Area =24"*0.125"=3sq.in.

Excess Thickness =1.163-0.950=0.213" Reinforcement Volume =3*0.213=0.638cu.in.

Volume 3 Area =1.5"*3"=4.5sq.in.

Excess Thickness =0.955-0.950=0.005" Reinforcement Volume =4.5*.005=0.023cu.in.

Volume 4 Area =1.5"*3"=4.5sq.in.

Excess Thickness =1.095-0.950=0.145" Reinforcement Volume =4.5*0.145=0.653cu.in.

REV O M86-10 SH 6 of 12 TOTAL REINFORCEMENT VOLUME AVAILABLE: 6.579cu.in.

REQUIRED REINFORCEMENT VOLUME: 5.441cu.in.

CONCLUSIONS:

-The as found wall thickness of the piping Can withstand up to hot standby pressure.

-Short term (1%) transient capabilities are within the worst case pressure load for all FSAR Chapter 14 analyses.

-There is 21% excess reinforcement available in the surrounding pipe wall to ensure the structural integrity of the piping system.

NOTE: Longitudinal stresses were analyzed by Bechtel independently from this analysis. Bechtel's results (Letter Number CC-A7966, dated 3DEC86) and these calculation conclusions were consolidated into one report.

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ULTRASONIC THICENESS14EASURE&iENT RECORD

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- NOTES -

Et. A 3h' A. ID #: 80 - D'- /OE ~ 08

1. Show Starting Point for inspection Points

2. Show Numbering Sequence for inspecticn B. PLPE DIAMETER:

39 Points

3. Show Component Orientation (e.g., Looking C. GRID SPACING:

Up, Down, North, South, Etc.) To Establish a Frame of Reference D. MIN THICKNESS FOUND:

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4. Attach Print Out of Pipe Wall Thickness

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CALCULATION REVIEW RECORD ' Number f - (( - lh Calculation Title 4/t !Mp? /M // / fNfN - Originator Of Reviewer [INQt Number of Pages /2 Review Scope (Check as applicable) \\tetho' d of Analysis j Assumptions Input Information ,v/4 Computer Code Application / Check of Sample Calculation / Spot Check of Mathematics / Reasonableness of Results ar/> Complete Check of Mathematics v4 Independent Calculation 1 1 t CC 2314 p.1 of 3

ItEVISION O DESP-6 D2 ^" " l, [ [1( f lb kVO WD Method of Analysis YES NO N/A Y"$ SYs'f-W=> 4 Y b# hhy-W 2/M SN * (U ts>Ltd e DJ/ t f,uaed*4 M

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Ptl/ MSM hgf$e poTe N 2. ten d p s type of calculation and the use and acceptability of the results (i.e., margin to limits)?. f/u - & * [ % v f,<-afd

3. Is the method in accordance with codes, standards and g

regulatory requirements? -N( /w hQ baf d Ward /f <

4. If so, which numbers.

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5. Has the method been employed elsewhere in industry or in license applications? E m

,x p/ a n y,u g / d

6. If so, where?

4 'l b - Assumptions

1. What assumpt on are necessary to perform the calculation?

~ %h

• , n'stm ed urJf-ad Q fedaf,a4 -G r/4** de/.

Inpuf'InformationN Z 'e~tu k -!!W-u k'f & & -n *%M a 7 aers /3 7/./, /o y. /. f M A w. 3.

1. Are inputs into the calculation stated and their source

/ identified?

2. Is the input information from the latest availabic

/' revision to the source document?

3. Is the status (preliminary, conceptual, etc.) of the input t/

source identified for later confirmation of the validity of Mk %td y'O the input? (e

4. Are the inputs sufficient considering the purpose of the 2

calculation? Computer Code Application

1. Are all codes used identified along with source, computer

[ type, inputs, and outputs?

2. Has the code being used been adequately verified?

3. Explain:

CC 2314 p. 2 of 3

REVISION 0 DESP-6 D3 Attachment D ('/1LC M - E le - 10 EI ld O - ~ * ~ YES NO N/A

4. Is the code suitable for the present analysis?

/ /Y h

5. Does the computer model (noding, time steps, etc.)

adequately represent the physical systems?

6. Explain:

Reasonableness of Results

1. Is the magnitude of the result reasonable?

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2. Explain:

Om M wg4 (d/ & s 4 Lt eu~ s ueyrn akw }ps 1 mA L.

3. Are the direction of trends reasonable?

[

4. Explain:

9 CC 2314 p. 3 of 3

9 BALTIMORE GAS AND ELECTRIC COMPANY 9364501 1908266 s.no,,., 'WUhndio:~J NVOICE NO. PURCHASE ORDER 1 r D 5F[ f DISCOUNr j kr7 A s.e4'y i 1 l l i 6XX476 ,12-12-86 l l$150.00 l ISI Program Regtiest for Relief from ASME Code Section 11 l requiremerit determine'd to be impractical l l 4 i 'I i [ TOTALS > l $150.00 Cl[,F/,7" ' l"Z.,- 12-12-86 i I isi5 BALTIMORE GAS AND ELECTRIC COMPANY DEC12 8r, RALTIMORE, MARYLAND 21703 . _ Z diow - 7 " n.n wdeQ1 PAY EXACTLY

• • 150.00**

$150.00** l 1908266 i i l TO THE U.S. NUCLEAR REGU1ATORY COMMISSION ** l ORDER Washington, D.C. 20555 OF ,[,_, i viNro MARY LAND NATIONAL BANK r n R A LM.'On C, M A n Y L A ND Y, UU'%I'UR y j e n' 1908 2 G G n' i:0 5 2000 LG8i: OGOm19L A n' 42-MFD . -}}