ML20083B560

Forwards Request for Relief for Noncode Repair on Ms Drain Line SHPD-1-601-Q2 for NRC Review & Approval.Informs That Pinhole Leak Discovered in Line on 950428 Which Could Not Be Isolated

ML20083B560
Person / Time
Site:	Beaver Valley
Issue date:	05/04/1995
From:	Noonan T DUQUESNE LIGHT CO.
To:	NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
NUDOCS 9505120100
Download: ML20083B560 (16)

Text

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%[k ouquesneupcompany =:re-suppin9p n.e4 ison ooo4 May 4,1995

<4m 393-re22 1

TMMAS P. NOONAN Fax (4m 393-49o5 j

g Vice Pgent U. S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, DC 20555-0001

Subject:

Beaver Valley Power Station, Unit No. I Docket No. 50-334, License No. DPR-66 Request for Relief for a Non-Code Repair On Main Steam Drain Line 11" SHPD-1-601-Q2 Attached for NRC review and approval is a request for relief for a non-code repair.

on main steam drain line li" SHPD-1-601-Q2. A pinhole leak was discovered in this line on April 28, 1995. This leak cannot be isolated and code repaired during plant operation, and a code repair would necessitate a plant shutdown and cooldown to Mode 5. Based on the above and the guidance provided by Generic Letter 90-05, a code repair during power operation is imprac'ical.

Therefore, pursuant to 10 CFR 50.55a(gX6Xi), it is requested that the NRC grant relief for a temporary non-code sepair to be used until the next entry into Mode 5, at which time a code repair will be performed.

This request was discussed with the NRC staff during telecons on May 3,1995.

Based on these discussions, the NRC staff provided verbal approval for the non-code repair on May 3,1995 at 1935 hours0.0224 days <br />0.538 hours <br />0.0032 weeks <br />7.362675e-4 months <br />, contingent upon their review and approval of the formal submittal.

If there are any questions concerning this matter, please contact Mr. N. R. Tonet at (412) 393-5210.

Sincerely, SVnd g5gogok75oo$334 Thomas P. No nan p

PDR Attachment DELIVERING c:

Mr. L. W. Rossbach, Sr. Resident Inspector 0l Mr. T. T. Martin, NRC Region I Administrator 0\\

ouatiiY Mr. D. S. Brinkman, Sr. Project Manager ENERGY 110015

4 DUQUESNE LIGHT COMPANY Nuclear Power Division Beaver Valley Power Station Unit No.1 Roquest for Relief for a Non-Code Repair on Main Steam Drain Line 11" SHPD-1-601-02 On April 28,1995, with Beaver Valley Unit 1 (BV-1) in power cperation, a pinhole leak j

was discovered on main steam drain line 11" SHPD-1-601-Q2 by a plant operator performing a routine tour of the main steam isolation valve room. The insulation was j

removed from this line and a small steam leak was found on the elbow socket weld connection between main steam line 32" SHP-56-601-Q2 and valve TV-MS-111A (se-Figure 1).

l The leak is located on a section of Class 2 high-energy piping on the Main Steam System. This leak cannot be isolated and code repaired during power operation. Based on the above and the guidance provided by Generic Letter 90-05, " Guidance for Performing Temporary Non-Code Repair of ASME Code Class 1, 2, and 3 Piping," a code repair during power operation is impractical. Therefore, pursuant to 10 CFR 50.55a(g)(6)(i), it is requested that the NRC grant relief for a temporary non-code repair l

to be used until the next entry into Mode 5, at which time a code repair will be -

I performed.

i Description of System Function l

l Main steam drain line li" SHPD-1-601-Q2 has developed a pinhole steam leak at the

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base of the pipe-to-elbow fitting socket weld. This line is 11" A-106 Grade B extra i

strong carbon steel, and is part of the high pressure steam drain system which removes moisture from the main steam system. The normal operating (100% power) pressure and j

temperature of this line are 800 psig and 516 F, respectively. The design pressure and j

temperature of this line are 1,100 psia and 560 F, respectively. To date, this line has experienced 46 thermal cycles. A cycle is defined as a heatup from Mode 5 to Mode 4 and subsequent return to Mode 5.

i P

Evaluation of Flaw l

A non-destmetive examination of the flaw using magnetic particle, liquid penetrant, radiography, and ultrasonic (UT) examination techniques was considered. Limited UT inspections of the elbow, upstream and downstream piping were conducted and indicated i

nominal wall thickness (see Attachment 1). Comprehensive UT examination and other NDE methods were not feasible due to the temperature of the pipe, presence of a steam I

leak, configuration of the socket weld, or the proximity to the main steam line.

1 Due to the lack of NDE results available to characterize the flaw, an ev:.luation of susceptible failure mechanisms was performed to provide assurance that the structural

)

integrity of the line is maintained. This review considered fatigue from vibration and l

l

j 1

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Beaver Volley Power Station Unit No.1 Request for Relief for a Non-Code Repair on j

l Main Steam Drain Line It" SHPD-1-601-Q2 1

Page 2 thermal cycling, sustained over-stress, erosion / corrosion and steam flashing with the following results.

Fatinue A walk down of the piping was performed to assess the potential for piping fatigue f

due to vibration and thermal cycling.

The main steam line is rigidly suppoited (anchored at the containment penetration and a five-way restraint at the valve house wall). No vibration was observed on the i

drain line.

l The potential for thermal cycling was assessed. The socket welded connection is within close proximity of the main steam line such that the connection sees the i

same temperature as the main steam line.

1 Based on the above, fatigue at this location due to vibration or thennal cycling is not considered to be significant.

I Sustained Over-Stress l

1 The stress calculation of record was reviewed to determine the state of stress in the l

line. The various design parameters, including deadweight, thermal, and seismic l

were reviewed. The line meets design requirements.

l l

Erosion / Corrosion i

The main steam drain line is potentially susceptible to flow accelerated corrosion (FAC). However, the location of the specific leak (through the upstream fillet weld of the elbow) is not indicative of a typical erosion / corrosion wear location. In addition, limited UT inspection results showed no wall thinning in the areas of l

piping above or below the weld.

Flashina This location is continuously at main steam line pressure. Therefore, phase change /

flashing will not occur.

The review of the above mechanisms provides reasonable assurance that the structural integrity of the line is maintained and, when combined with the results of the limited UT inspections, it has been concluded that the leak is a result of a localized weld defect.

I I

Beaver Valley Power Station Unit No.1 l

Request for Relief for a Non-Code Repair on Main Steam Drain Line 11" SHPD-1-601-Q2 Page 3 l

Non-Code Repair An engineered mechanical clamp designed to meet the load bearing requirements of the piping considering a complete through-wall 360 circumferential flaw will be installed j

consistent with the guidance provided by Generic Letter 90-05 for Class 2 piping non-code repairs. The installed design of this clamp with its associated strongbacks is shown in Figure 2.

j i

In addition to being designed to meet the piping load bearing requirements assuming a complete through-wall 360 flaw, the engineered mechanical clamp assembly is designed in accordance with the design requirements of ASME Code Case N-523. The highest stresses in the clamp assembly are well below code allowables and substantially below yield stress for the design temperature.

l

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A stress evaluation of the piping configuration with the additional mass of the engineered i

mechanical clamp and associated strongbacks was performed.

The evaluation considered all design basis loading conditions including pressure, thermal, seismic, and i

main steam isolation valve closure. The results of the evaluation were acceptable.

! provides the piping stress analysis results. In all cases, the piping stresses are well below code allowables and substantially below yield stress for the design temperature.

Due to the erosion effects of an active steam leak, it is desired to minimize the leak as much as possible. In order to accomplish this, the engineered mechanical clamp will be injected with thermally-setting sealant which will fill the small space between the clamp and the piping. No credit is given to this sealant for structural integrity, and its only function is to minimize leakage.

Temporary metal support of the drain line will be provided before installation of the clamp assembly and will remain in place until the line is code repaired. Appropriate i

protective clothing will be worn by personnel during the installation of the clamp assembly. The installation of the engineered mechanical clamp will be in accordance with an approved procedure and controlled under the temporary modification process.

l In support of the temporary modification process, a 10 CFR 50.59 safety evaluation was prepared to address the effects of a through-wall 360 flaw which is assumed in the analysis of the clamp. The radiological and environmental qualification effects of this condition were reviewed for impact on the following design basis accidents as described in the Beaver Valley Unit 1 Updated Final Safety Analysis Report (UFSAR).

UFSAR Section 14.1.13, " Accidental Depressurization of the Main Steam System" e

Besver Valley Pcwer Station Unit No.1 Request for Relief for a Non-Code Repair on Main Secam Drain Line 11" SHPD-1-601-Q2 Page 4 UFSAR Section 14.2.4, " Steam Generator Tube Rupture" e

l UFSAR Section 14.2.5.1, "M4jor Secondary System Pipe Break" UFSAR Section 14.2.11, " Minor Secondary System Pipe Break" e

The evaluation concluded tha; with the installation of the engineered mechanical clamp, there was no increase in the ptobability of occurrence or the consequences of an accident or malfunction of equipment inportant to safety as previously evaluated in the UFSAR, l

no new possibility for an accident or malfunction of a different type than previously l

l evaluated in the UFSAR, and no reduction in the margin of safety as defined in the basis i

for any technical specification. This evaluation was reviewed and approved by the Onsite Safety Committee.

j System Interactions and Hazards Review A system interactions and hazards review was performed, which included a walkdown of i

the area to identify any safety related components that could be affected. This review l

postulated a complete (360 ) circumferential break at the leak location. The effects of pipe whip, jet impingement / fluid spray, and flooding were reviewed with the following results:

Pipe Whio The location of the postulated break is immediately adjacent (less than 6") to the 32" main steam line. In the event of a pipe break, the small intact segment of piping (less than 6") that experiences sustained pressure cannot produce any adverse impact (i.e., cannot whip). The downstream piping is adequately restrained and does not experience a sustained fluid source following the break. Therefore, j

the downstream piping also cannot produce any adverse effects since it will not whip.

l l

Jet Imuingement/ Fluid Sorav l

l The jet impingement / fluid spray that could be produced from a leakage crack or a j

complete circumferential failure was reviewed to determine its effect on adjacent l

equipment / components. Based on the results of this review and the area walkdown, j

l no safety related components are located in the zone of influence of the jet l

l impingement / fluid spray; therefore, no adverse effects will occur.

l i

.- -...J

Beaver Valley Power Station Unit No. I Request for Relief for a Non-Code Repair on Main Steam Drain Line li" SHPD-1-601-Q2 Page5 Flooding The existing flooding analysis for the area is not affected since a break on li" SHPD-1-501-Q2 is enveloped by existing postulated breaks in the 4" decay heat line (reference UFSAR Section D.5 " Valve Cubicle and Pump Area").

Auemented Insnections Augmented visual VT-2 leakage examinations were performed at the similar locations off the "B" and "C" main steam lines (two locations). No evidence ofleakage or piping degradation was found. Monitoring in the area of these two similar locations will continue as part of the normal plant operator tours which are conducted once per shift.

The non-code repair will also be monitored to provide continuing assurance of structural integrity. The plant operators will observe the non-code repair once per shift and report any degradation to the control room for engineering evaluation. The above augmented inspections will continue until the piping is code repaired.

In addition, the clamp assembly bolting will be retorqued following any partial plant cooldown into Mode 3 before re-entry into Mode 2.

Conclusion The structural integrity of 11" SHPD-1-601-Q2 will be maintained with the installation and continued monitoring of the engineered mechanical clamp.

This clamp was designed to meet the load bearing requirements of the piping assuming a complete I

through-wall 360 flaw, as provided in the guidance of Generic Letter 90-05. Therefore, it is requested that the NRC grant relief for a temporary non-code repair to be used until the piping can be code repaired during the next entry into Mode 5.

i l

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MAIN STEAM l'1/2 INCH DRAIN LINE STRESS EVALUATION YTRESS FSAR Load Criteria Point Member Max Allow Equat.

Case (Psi)_ _(Psi)_

j N

Sustained B.2-4 4 Ssl=Slp+Sdw 5000 NOZZ 4135 15000 Occasional B.2-5 19 Socc=Slp+Sdw+(SRSS-Sn) 5000 NOZZ 9816 18000 U

Thermal B.2-7 2 Sth=Sexp+Sanc 5000 NOZZ 16593 33365 I

F

, Occasional B.2-6 20 Socc=Slp+Sdw+(SRSS-Sf) 5000 NOZZ 14199 27000 I

HYD ; Sustained B.2-4b n/a Shsl=Stp+Sdw ln/a n/a n/a

!n/a l

Allowable:

M at: lA105, git. B i

B.2-4 =

Sh B.2-5 =

1.2 Sh Sc =

15000 Psi at Amb.

B.2-6 =

1.8 Sh Sh=

15000 Psi at 600F B.2-7 =

[(1.25)(Sc) +(.25)(Sh) + (Sh-ISlp + Sdwl)]f f=

1 B.2-4b =

1.2 Sh (ANSI B31.1-1967, section 102.2.4) d Pipe inside diameter in D

Pipe out:ide diameter in f

Stress range reduction factor for cyclic conditions n/a i

Stress intensification factor n/a Mbdw Resulting bending moment due to deadweight in.lb i

Mbof Resulting bending moment due to occasionalload in.lb l

Mbon Resulting bending moment due to occasionalload in.lb Mbth Resulting bending moment due to thermalload in.lb i

Midw Resulting torsional moment due to deadweight in.lb Mtof Resulting torsional moment due to occasionalload in.lb Mton Resulting torsional moment due to occasionalload in.lb Mtth Resulting torsional moment due to thermalload in.lb P

Design pressure psi Pt Test pressure psi Sanc Thermal stress due to thermal anchor movements psi Sc Allowabic stress at ambient (70F) tetrperature psi Sdw Stress due to moment caused by deadweight psi l

Serp Thermal stress due to thermal expansion psi Sf Stresses due to occasionalloads (SSE, relief valve discharge) psi l

Sh Allowable stress at maximum operating temperature psi.

l Shst Sustained load stress due to hydro test psi l

Slp Longitudinal pressure stress based on design pressure psi i

'Sn Stresses due to occasionalloads (OBE, relief valve discharge) psi Socc Totaloccasionalstresses psi

'Ssl Total Sustained load stress psi Sth Thermalstresses psi Stp Longitudinal stress based on test pressure psi Z

Pipe sectionalmodulus in ^ 3 l

Equation B.2-4. 5. 6. 7 & 4b. respectively l

[P'd ^ 2/(D ^ 2-d ^ 2])+[(iMbdw/Z) ^ 2 +4'(Mtdw/2Z) ^ 2)] ^.5

[P'd ^ 2/(D ^ 2-d ^ 2])+[(iMbsl/Z) ^ 2+4*(MtsL/4Z) ^ 2)] ^.5 +[(iMbon/Z) ^ 2+4*(Mton/2Z)] ^.5.

[iMbth/Z) ^ 2+4*(Mtth/2'Z) ^ 2] ^.5

[P'd ^ 2/(D ^ 2-d ^ 2])+[(iMbst/Z) ^ 2+4'(Mtsl'2Z) ^ 2)] ^.5 + [(iMbon/Z) ^ 2 +4*(Mton/2Z)] ^.5 i

l IPt'd ^ 2/(D ^ 2-d ^ 2])+I(iMbdw/Z) ^ 2 +4*(Mtdw/2Z) ^ 2)] ^.5 ATTACIIMENT 2 Page 1 of 5

MPSRf4M de4*W WEc.o MAIN STEAM 11/2 INCH DRAIN LINE STRESS EVALUATION ITRESS FSAR Load Criteria Point Member Max Allow Equat.

Case (Psi)_

(Psi)

N Sustained B.2-4 4 Ssl=Slp+Sdw 5 ELB 4501 15000 i

Occasional B.2-5 19 Socc=Slp+Sdw+(SRSS-Sn) 5 ELB 7832 18000 i

I j

U

[ Thermal B.2-7 2 Sth=Sexp +Sanc 5 ELB 14462 32999 1

F l Occasional B.2-6 20 Socc=Slp+Sdw+(SRSS-Sf) 5 ELB 11006 27000 HYD Sustained B.2-4b n/a Shsl=Stp+ W n/a n/a n/a k

Allowable:

~~

M at: AffGR. B B.2-4 =

Sh B.2-5 =

1.2 Sh Sc =

15000 Psi at Amb.

B.2-6 =

1.8 Sh Sh =

15000 Psi at 600F B.2-7 =

[(1.25)(Sc) + (.25)(Sh) + (Sh-ISip + SdwI)]f f=

1 l

B.2-4b =

1.2 Sh (ANSI B31.1-1967, section 102.2.4)

.d Pipe inside diameter in D

Pipe outside diameter in f

Stress range reduction factor for cyclic conditions n/a t

i Stress intensification factor n/a Mbdw Resulting bending moment due to deadweight inJb Mbof Resulting bending moment due to occasionalload in.lb Mbon Resulting bending moment due to occasional load in.lb j

Mbth Resulting bending moment due to thermalload in.lb j

Midw Resulting torsional moment due to deadweight in.lb Mtof Resulting torsional moment due to occasionalload in.Ib lMton Resulting torsional moment due to occasionalload in.lb

'Mtth Resulting torsional moment due to thermalload in.lb l

P Design pressure psi l

Pt Test pressure psi l

Sanc Thermal stress due to thermal anchor movements psi Sc Allowable stress at ambient (70F) temperature psi

Sdw l Stress due to moment caused by deadweight psi l

'Scrp Thermal stress due to thermal expansion psi Sf Stresses due to occasionalloads (SSE, relief valve discharge) psi Sh Allowable stress at maximum operating temperature psi lShst Sustained load stress due to hydro test psi j

ISip Longitudinal pressure stress based on design pressure psi Sn Stresses due to occasional loads (OBE, relief valve discharge) psi Soce Totaloccasionalstresses psi Ssl TotalSustained load stress psi Sth Thermalstresses psi Stp Longitudinalstress based on test pressure psi Z

IPipe sectionalmodulus in ^ 3 Eguation B.2-4. 5. 6. 7 & 4b. respectively

[P* d ^ 2/(D ^ 2-d ^ 2])+ [(iMbdw/Z) ^ 2 +4*(Mtdw/2Z) ^ 2)] ^.5

[P'd ^ 2/(D ^ 2-d ^ 2])+[(iMbst/Z) ^ 2+ 4*(Mtsl/4Z) ^ 2)] ^.5 + [(iMbon/Z) ^ 2 +4'(Mton/2Z)] ^.5

[iMbth/Z) ^ 2+4 *(Mtth/2'Z) ^ 2] ^.5

[P'd ^ 2/(D ^ 2-d ^ 2])+[(iMbs!/Z) ^ 2+4'(Mtst/2Z) ^ 2)] ^.5 +[(iMbon/Z) ^ 2+4*(Mtord2Z)] ^.5 IPt'd ^ 2/(D ^ 2-d ^ 21)+l(iMbdw/Z) ^ 2+4*(Mtdw/2Z) ^ 2)l^.5 ATTACHMENT 2 Page 2 of 5 i

l

DoWWsWL4es4Leod WSee MAIN' STEAM 1 1/2 INCH DRAIN LINE STRESS EVALUATION STRESS FSAR Load Criteria Point Member Max Allow Equat.

Case (Psi)_

(Psi) l SustainedB.2-4 4 Ssl=Slp+Sdw 10 ELB 3895 15000 N

I Occasional B.2-5 19 Socc=Slp+Sdw+(SRSS-Sn) 10 ELB 13390 18000 l

U Thermal B.2-7 2 Sth=Sexp+Sanc 10 ELB 14657 33605 lF iOccasional B.2-6 20 Socc=Slp+Sdw+(SRSS-Sf) 10 ELB 20294 27000 HYD Sustained B.2-4b n/a,Shsl= Stp+Sdw a/a n/a n/a

!n/a Allowable:

M at: lA105, GR. B B.2-4 =

Sh B.2-5 =

1.2 Sh Sc =

15000 Psi at Amb.

B.2-6 =

1.8 Sh Sh =

15000 Psi at 600F l

B.2-7 =

((1.25)(Sc) + (.25)(Sh) + (Sh-ISlp + Sdwl)]f f=

1 B.2-4b =

1.2 Sh (ANSI B31.1-1%7, section 102.2.4)

(

jd Pipe inside diameter in l

lD Pipe outside diameter in l

if Stress range reduction factor for cyclic conditions n/a i

Stress intensification factor n/a Mbdw Resulting bending moment due to deadweight in.lb Mbof Resulting bending moment due to occasionalload in.lb Mbon Resulting bending moment due to occasionalload in.lb Mbth Resulting bending moment due to thermalload in.lb Mtdw Resulting torsional moment due to deadweight in.lb Mtof Resulting torsional moment due to occasionalload in.lb Mton Resulting torsional moment due to occasionalload in.lb Mtth Resulting torsional moment due to thermalload in.lb P

Design pressure psi

)

iPt Test pressure psi

!Sanc Thermal stress due to thermal anchor movements psi l

Sc Allowable stress at ambient (70F) temperature psi Sdw Stress due to moment caused by deadweight psi l Serp Thermal stress due to thermal expansion psi ISf Stresses due to occasionalloads (SSE, relief valve discharge) psi lSh Allowable stress at maximum operating temperature psi

'Shst Sustained load stress due to hydro test psi iSlp Longitudinal pressure stress based on design pressure psi iSn Stresses due to occasionalloads (OBE, relief valve discharge) psi lSocc Totaloccasionalstresses psi lSsl Total Sustained load stress psi Sth Thermalstresses psi Stp Longitudinal stress based on test pressure psi Z

Pipe sectional modulus in ^ 3 Eauation B.2-4. 5. 6. 7 & 4b. respectivelv

[P'd ^ 2/(D ^ 2-d ^ 2])+[(iMbdw/Z) ^ 2 +4*(Mtdw/2Z) ^ 2)] ^.5

[P*d ^ 2/(D ^ 2.d ^ 2])+ [(iMbst/Z) ^ 2 +4*(Mtst/4Z) ^ 2)] ^.5 +[(iMbon/Z) ^ 2 +4'(Mton/2Z)] ^.5

[iMbth/Z) ^ 2+4'(Mtth/2'Z) ^ 2] ^.5

[P'd ^ 2/(D ^ 2-d ^ 2])+[(IMbst/Z) ^ 2 +4'(Mtst/2Z) ^ 2)) ^.5 + [(iMbon/Z) ^ 2 +4*(Mton/2Z)] ^.5 iPt'd ^ 2/(D ^ 2-d ^ 2])+l(iMbdw/Z) ^ 2+4'[Mtdw/2Z) ^ 2)1^.5 ATTACl! MENT 2 Page 3 of 5

WPry:ya4k9 /Auf &iN%C l

MAIN STEAM l'1/2 INCH DRAIN LINE STRESS EVALUATION.

STRESS FSAR Load Criteria Point Member Max Allow Equat.

Case (Psi)

(Psi) i N

Sustained B.2-4 4 Ssl=Slp +Sdw 13 VAL 5107 15000 l

l &

' Occasional B.2-5 19 Socc=Slp+Sdw+(SRSS-Sn) 13 VAL 8530 18000 i

j U Therrnal B.2-7 1 Sth=Sexp+Sanc 13 VAL 6542 32393 F

ccasional B.2-6 20 Socc=Slp+Sdw+(SRSS-Sf) 13 VAL 10906 27000 i

i LHYD ! Sustained B.2-4b n/a Shsl=Stp+Sdw n/a n/a n/a n/a Allowable:

Mat: lA105, GR. B B.2-4 =

Sh B.2-5 =

1.2 Sh Sc =

15000 Psi at Arnb.

B.2-6 =

1.8 Sh Sh=

15000 Psi at 600F B.2-7 =

[(1.25)(Sc) +(.25)(Sh) + (Sh-ISlp + Sdwl)]f f=

1 B.2-4b =

1.2 Sh (ANSI B31.1-1%7, section 102.2.4) d Pipe inside diameter in D

Pipe outside diameter in f

Stress range reduction factor for cyclic conditions n/a Il Stress intensification factor n/a lMbdw IResulting bending moment due to deadweight in.lb Mbof Resulting bending moment due to occasionalload in.lb Mbon Resulting bending moment due to occasionalload in.lb Mbth Resulting bending moment due to thermalload in.lb Mtdw Resulting torsional moment due to deadweight in.lb

!Mtof Resulting torsional moment due to occasionalload in.lb

[Mton Resulting torsional moment due to occasionalload in.lb lMtth Resulting torsional moment due to thermalload in.lb lP Design pressure psi lPt Test pressure psi

'Sanc Thermal stress due to thermal anchor movements psi Sc Allowable stress at ambient (70FJ temperature psi Sdw Stress due to moment caused by deadweight psi Serp Thermal stress due to thermal expansion psi Sf Stresses due to occasionalloads (SSE, relief valve discharge) psi Sh Allowable stress at maximum operating temperature psi lShsl Sustained load stress due to hydro test psi iSip Longitudinal pressure stress based on design pressure psi iSn Stresses due to occasionalloads (OBE, relief valve discharge) psi lSocc Totaloccasionalstresses psi lSsl TotalSustained load stress psi ISth iThermalstresses psi ktp Longitudinal stress based on test pressure psi

[Z Pipe sectional modulus in ^ 3

' Equation B.2-4. 5. 6. 7 & 4b. respectively

[P* d ^ 2/(D ^ 2-d ^ 2])+[(iMbdw/Z) ^ 2 +4*(Mtdw/2Z) ^ 2)] ^.5

[P'd ^ 2/(D ^ 2-d ^ 2])+[(iMbst/Z) ^ 2+4'(Mtst/4Z) ^ 2)] ^.5 + [(iMbon/Z) ^ 2 +4'(Mton/2Z)] ^.5

[iMbth/Z) ^ 2+4'(Mtth/2*Z) ^ 2] ^.5

[P* d ^ 2/(D ^ 2-d ^ 2])+[(iMbst/Z) ^ 2 +4'(Mtst/2Z) ^ 2)] ^.5 + [(iMbon/Z) ^ 2+4'(Mton/2Z)] ^.5

..lPt'd_^ 2/fD ^ 2-d ^ 2])+((iMbdw/Z) ^ 2+4'{Mtd.w/2Z) ^ 2)] ^.5 ATTACHMENT 2 Page 4 of 5

W SM/M NWf NdHM'

^

l l

MAIN STEAM 1 1/2 INCH DRAIN LINE STRESS EVALUATION STRESS FSAR Load Criteria

-Point Member Max Allow Equat.

Case (Psi)_

(Psi)

N Sustained B.2-4 4 Ssl=Slp+Sdw 14 VAL 4842 15000 i &

Occasional B.2-5 19 Socc=Slp+Sdw+(SRSS-Sn) 14 VAL 8404 18000 U

Thermal B.2-7 1 Sth=Sexp+Sanc 14 VAL 11269 32658 l OccasionalB.2-6 20 Socc=Slp+Sdw+(SRSS-Sf) 14 VAL 10826 27000 F

HYD [ SustainedB.2-4b n/a Shsl=Stp+Sdw a

n/a ha ha Allowable:

Mat: lA105, Gil. B B.2-4 =

Sh B.2-5 =

1.2 Sh Sc =

15000 Psi at Amb.

B.2-6 =

1.8 Sh Sh =

15000 Psi at 600F B.2-7 =

[(1.25)(Sc) + (.25)(Sh) + (Sh-ISlp + Sdwl)]f f=

1 B.2-4b =

1.2 ShLANSI B31.1-1967, section 102.2.4) d Pipe inside diameter in D

Pipe outside diameter in f

Stress range reduction factor for cyclic conditions n/a

i Stress intensification factor n/a IMbdw Resulting bending moment due to deadweight in.lb lMbof Resulting bending moment due to occasionalload in.lb l

Mbon Resulting bending moment due to occasionalload in.Ib

,Mbth Resulting bending moment due to thermalload in.lb Mtdw Resulting torsional moment due to deadweight in.lb Mtof _Resulting torsional moment due to occasionalload in.Ib Mton lResulting torsional moment due to occasionalload in.lb Mtth IResulting torsional moment due to thermalload in.lb P

Design pressure psi Pt Test pressure psi

. Sane Thermal stress due to thermal anchor movements psi lSe Allowable stress at ambient (70F) temperature psi l

lSdw Stress due to moment caused by deadweight psi

Sexp Thermal stress due to thermal expansion psi

!Sf Stresses due to occasional loads (SSE, relicf valve discharge) psi

!Sh Allowable stress at maximum operating temperature psi iShst Sustained load stress due to hydro test psi

[ Sip Longitudinal pressure stress based on design pressure psi (Sn Stresses due to occasional loads (OBE, relief valve discharge) psi lSocc Totaloccasionalstresses psi lSsl Total Sustained load stress psi iSth Thermalstresses psi IStp Longitudinalstress based on test pressure psi

!Z Pipe sectional modulus in^3 iEquation B.2-4. 5. 6. 7 & 4b. respectivelv

[P'd ^ 2/(D ^ 2-d ^ 2])+ [(iMbdw/Z)' ^ 2+4*(Mtdw/2Z) ^ 2)] ^.5

[P'd ^ 2/(D ^ 2-d ^ 2])+ [(iMbst/Z) ^ 2+4 *(Mtst/4Z) ^ 2)] ^.5+[(iMbon/Z) ^ 2+4'(Mton/2Z)] ^.5

)

[iMbth/Z) ^ 2+ 4'(Mtth/2*Z) ^ 2] ^.5 l [P'd ^ 2/(D ^ 2-d ^ 2])+[(iMbsl/Z) ^ 2+4*(Mtsl/2Z) ^ 2)] ^.5 + [(iMbon/Z) ^

_ [Pt'd ^ 2/(D ^ 2-d ^ 21)+[(iMbdw/Z) ^ 2+4'(Mtdw/2Z) ^ 2)] ^.5 ATTACHMENT 2 Page 5 of 5