ML20079K844
| ML20079K844 | |
| Person / Time | |
|---|---|
| Site: | Oyster Creek |
| Issue date: | 04/30/1991 |
| From: | MPR ASSOCIATES, INC. |
| To: | |
| Shared Package | |
| ML20079K841 | List: |
| References | |
| MPR-1226, NUDOCS 9111050040 | |
| Download: ML20079K844 (328) | |
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MPR Assocl Avts, INC.
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OYSTER CREEK NUCLEA!LGENERATING STAT 10lj I LEAK BEFORLj!R[AK EVALVA110N Of 1.50t ATION
[Q!QU!ELR SYST[M PIP _lRQ OVISIDL[0NTAINMENI MPR - 1226 Volume 1 g
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Prepared for:
General Public Utilities Nuclear Parsipp6ny, NJ April, 1991 I r l
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I 1050 CONNteticut AvtNut. N W. WASHINGTON. D.C. 2W6 202 659 2020 I oit1050040 911020 p rg<
p, ADOC K 05000219 PDR.
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MPR ASSOCIATES. INC, I
L, IABlf Of C0tilD415 hlVlt I
- 1. Introduction
- 2. Summary & Conclusions 2.1 Leak Detection Capability 2.2 Determination of Detectable flaw Sizes 1 2.3 Applicability of Analysis Method 2.4 fracture Mechanics Analyses
- 3. Applicability of leak Before Break Methodology 3.1 Intergranular Stress Corrosion Cracking (IGSCC)
I 3.2 3.3 Waterhammer fatigue .
3.4 Wall Thinning 3.5 Creep
- 4. Leak Detection Capability
- 5. Leak Rate Modeling
- 6. fracture Mechanics Analyses 6.1 Applied Loads 6.2 fracture Mecharics Methodology 6.3 Material Properties I 6.4 System Compliance 6.5 fracture Mechanics Results
- 7. references i men
- 8. Appendices
MPR ASSOCIATES. INC.
I Section 1 INTRODUC110N l 1his report summarizes the results of a leak before break evaluation of the isolation condenser system (105) steam supply and condensate return piping outside of the drywell at Oyster Creek Nuclear Generating Station. The purpose of the evaluation is to show that the likelihood of a double ended guillotine type pipe break in this system is very small. Consequently, the I dynamic effects of such a break need not be considered in the licensing basis for this system. Consideration of such effects would otherwise be required by General Design Criterion 4 of Title 10. Code of federal Regulations, Part 50.
The methodology used to evaluate the potential of the ICS piping to f ail unstably in the presence of large through-wall flaws is outlined in the draft version af Standard Review Plan (SRP) Section 3.6.3 (Reference 1).
The approach consists of determining postulated through wall flaw sizes I which result in leak rates substantially greater than the existing leak detection capability and evaluating the capability of the piping to accommodate these flaws without catastrophic rupture under severe losds (pressure, deadweight, and operating thermal loads in combination with the maximum calculated loads for the design safe shutdown earthquake). The specific steps in the evaluation and the recommended acceptance criteria given in SRP 3.6.3 (Draft) are as follows:
Demonstrate that the piping system is not susceptible to failure I .
mechanisms such as waterhammer, fatigue, intergranular stress corrosion cracking (IGSCC), wall thinning, or creep.
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L . Evaluate the plant leak detection capabilities to determine the detectable leak rate.
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. Calculate tSe expected leakage from through-wall flaws under normal operating pressure and determine the crack size which is predicted to leak at a rate ten times the detectable rate. This l
is the postulated flaw fo* fracture mechanics analyses.
l . Calculate the appiied loads and resulting stresses in the piping system for normal operating conditions plus safe shutdown I earthquake (SSE).
. For the loading condition noted above, determine the highest stress locations in the piping. These are the locations for postulated through wall flaws.
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. for the calculated loading, show that the postulated flaws are stable.
. Demonstrate a factor vf safety of at least 2 times the postulated crack length. That is, show that the crack size which l corresponds to unstable pipe failure for the applied loads is at least twice as long as the postulated flaw.
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. Demonstrate a factor of safety which is at least 1,41 times the applied load. That is, show that the load which corresponds to l
unstable pipe failure for the postulated crack size is at least 1.41 times the applied load.
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L 1he analyses described in this report are based upon the methods described above for demonstrating margin against unstable pipe rupture. The L remainder of this report contains the following main sections:
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. Sunnary & Conclusions a sunnary of the results and conclusions of the LBB evaluation.
. Leak Detection Capability describes the leakage detection I capability at Oyster Creek.
. Leak Rato Modeling describes the model used for predicting the leakage rate from through wall pipe cracks.
. Applicability of Leak Before Break Methodology - addresses the limitations imposed on the applicability of tBB analyses by SRp 3.6.3 (Draft}.
l . fracture Mechanics Analyses describes methodology and results of analyses performed as part of the evaluation.
. References.
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. Appendices include detailed methods and calculations used as part of the evaluation.
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MPR ASSOCIATES. INC.
I Section 2
$UMMARY AND CONCLUSIONS Analyses have been performed to determine if large through-wall flaws which would leak at a rate well beyond the limit of existing detection capability can be accommodated in the Oyster Creek ICS piping without unstable tearing or plastic section collapse. Specifically, evaluations have been performed to determine the leak detection capsbility for this piping at Oyster Creek, l to establish postulated circumferential through-wall flaw sizes which can be readily detected by these systems, and to determine whether such postulated flaws can result in an unstable double ended pipe rupture. The analyses were performed for postulated cracks in each of the four piping systems which make up the ICS piping: steam supply to condenser A, steam I supply to condenser B. condensate return from condenser A and condensate return from condenser B.
The analyses of the ICS piping meet all of the SRP 3.6.3 (Draft) analysis l criteria with one exception.
of two in terms of critical crack size. This margin is intended to account SRP 3.6.3 (Draft) recommends a safety margin for uncertainties in the fracture mechanics analysis methodology and leak detection capability (Reference 21). Although the margins on crack size for the ICS piping are greater than two in most locations, in a few cases the margin is as low as 1.75. As described in this report, a factor of 10 has already been applied on the calculated leak rate over the leak I detection capability to account for the leak detection and leak calculation uncertainty, furthe.*, in all cases examined, the critical crack size is limited by plastic collapse rather than unstable tearing. Plastic collapse can be predicted relatively precisely compared to unstable tearing fallt..e.
l Thus, the recommended margin of two is very conservative for the ICS piping. Considering the basis for the recommended margin cf two, the calculated margins are considered to provide adequate safety margin against 2-1 I
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I failure. More detailed summaries of the evaluations performed for the ICS piping are provided below.
2.1 Applicability of Analysis Method The SRP 3.6.3 guidelines do not provide for a leak before-break evaluation on a system where piping is subject to $ignificant environmental degradation mechanisms such as intergranular stress corrosion cracking (IGSCC), creep or erosion / corrosion wall thinning. The methodology is also l considered to be inappropriate for piping subject to high fatigue usage or waterhammer type loads. Each of these concerns was addressed in this evaluhtion.
Ifd(1 The ICS piping outside the drywell has been recently replaced I with Type 316NG material which is more resistant to IGSCC in BWR reactor conlant environments than traditional stainless steels, further, the isolation valves (which lie outside the drywell) have also been replaced with valves with bodies fabricated from low carbon l cast stainless steel with controlled ferrite content.
of NUREG 0313. Rev 2 (Reference 2), the ICS piping and valves are made By the criteria from IGSCC
- resistant" materials, pipe to-pipe welds have been made with controlled weld metal chemistry and ferrite content, as well as controlled joint geometry and heat input to reduce residual stress and heat affected zone sensitization to IGSCC. Welds between the new pipe and the existing isolation condenser nozzles (which are non resistant, high carbon stainless l steel) have baen made with the nozzle side protected by specially applied corrosion resistant cladding.
I It is planned to apply a stress improvement tretament (induction g heating or mechanical stress improvement) to all appropriate ICS weld
.m joints outside the drywell during the next refueling outage in order l to add a second IGSCC mitigator to those weld joints. All pipe-to-pipe welds will have at least two corrosion mitigators: low carbon 2-2 l
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I material or corrosion resistant clad plus a stress improvement treatment within 24 months of operation of the new piping. Thus, these joints can be considered ' Category A" resistant welds as defined in NUREG 0313 Rev 2. possible exceptions are tne welds between pipe g and valves and the welds at the itolaMon candenser nozzles where h stress improvement treatment may be impossible to apply effectively.
I Because of the special care taken to fabricate and install the replacement ICS pipe and fittings, it is considered toat the ICS piping outside the drywell is highly resistant to 1GSCC.
l Lau gn As part of this fracture methanics based leak before-break evaluation, a full ASME Code Section 111, Class 1 f atigue evaluation was performed on the 105 system outside the drywell. A conservative g
nurber of system actuations was astumed (10 per year) during which the condensate return piping was conserv41ively assumed to undergo a step I change in temperature fro- 70*f to 575'f (the system design temperature), in addition, conservative stress intensity factors were assumed for weld joints and discontinuities between pipe and fittings and within fittings. The calculated usage factors for 40 years of l operation were all f ound to f all below 0.2, with a Code allowalle of 1.0. Therefore, fatigue f ailure of the piping is not considered to be a centerr,.
A review of waterhammer events in isolation condenser I Rd nhammer systems nationwide shows that waterhammer has only been a serious concern at one CWR, Millstone 1. Based on the information provided in References 3 to 5, it appears that the frequent waterhammer events reported early on at Millstone 1 were due to f aulty feedwater regulator valve control after SCRAM combined with poor ICS steam supply line routing. Modification of the valve control logic +
eliminated the waterhammer events. A single waterhammer event was reported at Nine Mile poirt Unit I during plant startup testing. This was due to poor steam supply line routing. After the addition of 23 I
I drains, ICS waterhammer has not been observed at Nine Mile point Unit 1.
Oyster Creek has never reported an ICS waterhammer event. Post SCRAM water level control in the vessel has been adequate and the steam supply lines are well drained. The newly installed pipe maintains the good steam supply drain features of the original piping. GpVN has I also impicmented operating procedures which preclude operating the isolation condenser system when the reactor vessel level is in a range which could lead to a waterhammer event. Based on the good history at Oyster Creek, ICS waterhammer is not expected to be of concern.
Cf.mLArtOtll_Jhicaing Neither of these degradation mechanisms are considered to be possible in a relatively low temperature (550'f), low flow velocity system f abricated from stainless steel.
Based on the above considerations, it is concluded that the leak-before-break analysis rnethodology is applicable to the Oyster Creek 105 in acc;rdance with the guidelines of SRP 3.6.3 (Draft).
2.2 Leak Detection Capability The primary methods for detecting leakage from the ICS piping outside the drywell are visual inspections of the piping conducial St least daily and daily reactor building sump inleakage reports which, by administrative l limits, require investigation of inleakage to the sump exceeding 260 gallons per day. Secondary methods for detecting leaks include area temperature alarms in the vicinity of the steam supply and condensate return isolation valves, and reactor building air particulate radiation monitors.
I Based on an evaluation of these leak detection methods, it is concluded that daily inspections of the system, all of which is accessible, combined with daily sump inleakage reports, support a leak detection sensitivity for l the isolation condenser piping of 0.2 gallons per minute (gpm),
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2.3 Determination of Detectable flaw Sizes The leak rate of reactor coolant from postulated through-wall cracks in the
- ICS piping was predicted using a specialized computer program developed for this purpose. The flow model uses an fL/D loss mechanism through the crack to predict pressure drop, and a homogeneous choking model based on the crack exit plane stagnation pressure is used to evaluate critical flow.
l Estimates of flow from the cracks were obtained from the model and were confirmed to be conservative based on comparisons of model predictions to reported measurements of leakage from through wall cracks in test specimens.
The steam supply piping contains six sizes of pipe: 10" diameter schedules 80 and 100, 12" diameter schedules 80 and 100 and 1b" diameter schedules 80 and 100. The condensate return piping contains four sizes of piping: 8" diameter schedules 80 and 100 and 10" diameter schedules 80 and 100. Thus, there are a total of ten combinations of pipe size and fluid (steam in the steam supply lines and subcooled liquid in the condensate return lines).
Calculated leakage rate as a funstion of through wull crack size is shown in figures 2.1 and 2.2 for each pipe size / fluid combination.
SRP 3.6.3 (Draft) recommends that the leak rate for the postulated flaws used in fracture mechanics ana'yses be ten times the detectable rate, for the Oyster Creek ICS piping, this corresponds to a two gpm leak rate.
Based on the results of the crack size leakage analyses, the postulated circumferential, through wall flaw sizes chosen for fracture mechanics analyses are shown in Table 2.1. lhese crack lengths range from,about 64*
to 106' of pipe circumference.
2.4 fracture Mechanics Analyses The portion of the isolation condenser piping considered for leak before break analysis was that piping which lies outside containment between the containment penetrations and the isolation condenser nozzles. Piping inside the containment, while included in the stress analysis model, was not considered in the leak before break analysis. This is acceptable and 2-5
l in accordance with the intent of SRp 3.6.3 (Draft), since: (1) the components which are critical to this evaluation are the steam line isolation valves, all of which lie outside the drywell and would not be subject to jet loads resulting from breaks inside the drywell; and (2) the portion of piping outside the drywell is mechanically isolated from pipe I reaction loads resulting from a postulated break inside the drywell. The isolation is due to the high stiffness of the drywell penetration which acts like an anchor point.
l The applied loads on the ICS piping due to deadweight, thermal expansion and SSE were obtained from the ANSI /ASME B31.1 design stress analyses for g the ICS piping (References 6 to 9). The locations selected for fracture mechanics analyses are the highest loaded points in each system for each pipe size, or a total of 20 locations. In general, these locations I correspono to terminal ends of the piping, such as a condenser nozzle or drywell penetration, or change in pipe cross section, such as from schedult 100 to 80. These locations are identified in figures 6.1 to 6.4.
l The replacement ICS piping is Type 316NG stainless steel. The pertinent tearing modulus selected for fracture mechanics analyses is based on conservative data obtained for stainless steel t.asting material at operating temperature (550'). This value is 181.
I The results of tearing stability analyses are shown in Table 2.2. This table lists the calculated applied tearing modulus, T, for each fracture mechanics analysis location. Unstable crack growth (tearing) is predicted if the calculated value of the applied tearing modulus is greater than the material tearing modulus, T m. As can be seen, the calculated applied tearing modulus for each location is less than T m. No unstable tearing is predicted for the assumed through wall flaws under normal operating plus earthquake loads.
I The calculateo safety factors on applied load are shown in Table 2 3. The safety factors are all greater than 1.41 and therefore satisfy the criteria I recommended in SRP 3.6.3 (Draft).
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I I lable 2.3 also shows the safety factors in terms of crack size. In each case the limiting f ailure mode is plastic collapse rather than tearing instability, since tearing instability becomes unlikely for the very large track sizes evaluated here. As shown in lable 2.3, some of the analysis l locations do not quite meet the SRP 3.6.3 recommended criteria of a margin of two on crack size (the worst case is 1,75). However, as described above, considering the basis for the recommended margin of two, the calculated margins (minimum of 1.75) are considered to provide adequate safety margin against failure.
C.Oncl y11gr)
I It is concluded that sufficient mitigating actions have been taken at Oyster Creek to eliminate concerns with 1GSCC in the ICS piping. Further, I since no 4:aterhammer or f atigue concerns exist f or this system, use of SRP 3.6.3 (Draf t) trethods for leak-before-break analysis is appropriate and valid.
fracture mechanics analyses were performed that included the following conservatisms: (1) use of lower bound material tearing modulus (2) use of lower bound leak rates, (3) use of pipe minimum wall geometry for fracture I mechanics analyses, and (4) use of conservative GE/EPRI estimates of J-integral values. Results of the analyses show that, even with these I conservatisms, there is considerable margin against double-ended ruptures of the 105 piping.
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Table 2.1 2 GPH LEAKAGE CIRCUMfERENTIAL CRACK SIZES Piping fluid Pipe Size 0,y, a;g, Condensate 1035 psia, 549'r 8" Schedule 80 76' 5.72" Return Saturated liquid , , ,
10" Schedule 80 64* 6.00" 10" Schedule 100 73* 6.85" team Supply 1035 psia, 549'F 10" Schedule 80 93' 8.72" I Saturated Steam 10" .. 'dule 100 106' 9.94" l 12" Schedule 80 82' 9.12" 12" Schedule 100 94' 10.46" 16" Schedule 80 70' 9.77" 16" Schedule 100 80' 11.17" l
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I lable 2.2 CALCULAl[D APPLIED TEARING MODULUS RESUL15 I System Location (Node) Pipe Size Applied learing Modulus
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A - Condensate D04N 8" Schedule 80 1.8 003A 8" Schedule 100 2.3 808 10" Schedule 80 0.7 l A - Steam B01 809 10" Schedule 100 10" Schedule 80 0.7 2.8 801 10" Schedule 100 3.5 012 12" Schedule 80 3.6 I D10A 12* Schedule 100 4.4 g B19 16" Schedule 80 0.4 Bil 16" Schedule 100 0.5 B Condensate C28 8" Schedule 80 8.9 C26A 8" Schedule 100 11.9 C05 10" Schedule 80 0.8 10" Schedule 100 1.4 I B- uam B20 809 10" Schedule 80 5.9 B01 10" Schedule 100 4.6 D17 12" Schedule 80 4.7 004 12" Schedule 100 5.1 B15N 16" Schedule 80 0.9 I
B13 16" Sc,hedule_100 1.2
- To be compared with T xy - 181.
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I lable 2.3 SAFE 1Y FAC10RS I Safety SrJety I System location (Node) pipe Site factor on Applied load factor on Crack Len9th A - Condensate D04N 8" Schedule 80 3.83 2.56 003A 8" Schedule 100 3.54 2.26 B08 10" Schedule 80 5.05 3.20 l A - Steam 801 B09 10" Schedule 100 10" Schedule 80 5.12 3.23 2.86 2.07 B01 10" Schedule 100 2.90 1.82 012 12" Schedule 80 3.10 2.24 D10A 12" Schedule 100 3.11 2.02 B19 16" Schedule 80 6.53 3.16 B11 16" Schedule 100 5.95 2.75 B - Condensate C28 8" Schedule 80 2.32 2.10 C26A 8" Schedule 100 2.28 1.91 COS 10" Schedule 80 4.91 3.17 B20 10" Schedule 100 4.03 2.68 8 Steam B09 10" Schedule 80 2.47 1.87 B01 6 Schedule 100 2.57 1.75 D17 12" Schedule 80 2.92 2.19 l D04 12" Schedule 100 2.93 1.98 B15N 16" Schedule 80 4.69 2.91
_ B13 16" Schedule 100 4.30 2.54 I 2-10 E
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- - .- - - - - - - - - - - - - -T Calculated Leakage Rates -
8" Piaing 20, _-
j I
,! --- Sch 80 Condensate k Sch 100 Condensate l
315'-
l w l
~
m I T \
3 o 10 lF u_
w E .
x !
g 5l l' -
~~~~~~~"~ ' _ . _ _ _ _
0 0 25 50 75 100 125 150 Crack Angle (degrees)
Figure 2-1 1
Ca cula:ec Leakage Rates -
1C" Piping pg l l n
!l 1 Sch 80 Condensate i E !! Sch 100 Condensate 2 15 -4 i 3 l1 Sch 80 Steam 3m ! !, - "- Sch 100 Steam ct ,
310 '
O E i o .;
cn , .
a -
xm 5- .
e
- J j .
/ -- -
/
~~~"~' "" ~
- - - - - ~ - - -
- ~ - -
0 '
0 25 50 75 100 125 150 Crack Angle (degrees)
Figure 2-2
Calculated Leakage Rates -
12" Piping ,
2 0 r-- - - - - - - - - - - - - - - - - - - . -
r -- - - - - - - , - -___._ ]
I m
Sch 80 Steam E
- o. Sch 100 Steam 915 - '
m ;!
2 3:
o10l i .
E l ll
)
o ,
c) m ;;
x ,
$ 5l l 3
! i 04 , -==~~l
~ ~
, 7-- ,
J i
0 25 50 75 100 125 150 Crack Angle (degrees)
Figure 2-3
i Calculated Leakage Ra:es -
16" Piaing 20 i , 1
!i / j i i Sch 80 Steam '
l t-a.
Sch 100 Steam e15 ,- -
i e : j i
e i C !
! t l 3 O 10 d i u.
. i
, e '
O
.' m t
, x m 5" e
y l
- ,/ f f
- - > t l
0, 7"~ ~~~' .
i l 0 25 50 75 100 125 150 Crack Angle (degrees) ;
i l Figure 2-4 i
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- MPR ASSOCIATES, INC.
L Section 3 I~
' APPLICARillTY OF LEAK-BEFORE-BREAK HETH000 LOGY SRP 3.6.3 (Draft) recommends that the app'ication of leak before-break (LBB) analyses of high energy piping be subject to several limitations.
These limitations do not recommend the application of a LBB evaluation for I piping systems which are susceptible to failure from the effects of intergranular stress corrosion cracking (IGSCC), waterhammer or fatigue, 11 must also be shown that wall thinning and creep are not concerns. The susceptibility of the Oyster Creek ICS piping outside containment to each l of these pipe degradation mechanisms is discussed below.
3.1 Intergranular Stress Corrosion Cracking The Oyster Creek ICS piping is Type 316NG stainless steel. This type of stainless steel in the as-welded condition in a typical BWR environment has l shown superior resistant. to IGSCC in comparison to other austenitic stainless steels such as 304 or 316. Further, the isolation valves have also been replaced with valves made from low carbon cast stainless steel with controlled ferrite content. Both the piping and the val <'es are made I from IGSCC resistant materials as described by NUREG-0313, Rev.2, in addition, other steps have been taken or are planned by GPUN to further reduce the possibility of IGSCC occurring in the ICS piping. These steps, which include tight control of the welding process, stress improvement and application of corrosion resistant cladding, are described below.
The pipe to pipe welds have been made with controlled weld metal chemistry and ferrite content, as well as controlled weld joint geometry and heat input. This weld process control reduces the welding residual stresses in the weld and also reduces the potential for heat affected zone sensitization and the potential for IGSCC.
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h Welds between the new low carbon pipe and the existing isolation condenser r nozzles (which are non-resistant, high carbon stainless steel) were made with the nozzle side inside diameter protected by specially applied
- corresion resistant cladding. The cladding prevents the corrosive reactor coolant from contacting the sensitized weld heat affected zone in the high carbon material, it is planned to apply a stress improvement treatment (induction heating stress improvement or mechanical stress improvement) to all appropriate ICS weld joints outside the drywell during the next refueling outage. This procedure, which leaves the weld joint with favorable residual stresses to resist !GSCC, will add a second mitigator to those welds.
I As a result of the protective measures de*cribed above, crack development and crack growth due to the effects of iGSCC are not expected in the ICS piping. All of the welds outside containment, with the possible exception of the welds to valves and the condensers, will have two IGSCC mitigators (resistant material and stress improvement) and will meet the NUREG-0313, Rev.2 requirements for Category A welds. The valve and condenser welds may not have stress improvement due to the difficulty in applying stress improvement to these joints. However, they will still be fabricated from I resistant material.
3.2 Waterhammer There is documented evidence of ICS piping waterhammer events at only two i U.S. BWRs (References 3 to 5). These events occurred at Millstone and at Nine Mile Point Unit 1. The waterhammer events at NMP-1 occurred during start-up testing and were caused by condensate forming in the low points in the steam supply piping when the system was not operational. This water then became entrained in the steam on system actuation. System modifications were made to install drains in the piping low points and no waterhammer events have occurred since. Waterhammer events occurred at Millstone when the reactor vessel water level increased abcVe the ICS steam supply nozzle, allowing water to enter the steam supply piping. The 3-2
I Millstone operating procedures were revised to keep the water level lower and no waterhammer events have been reported since.
After the waterhammer events at Millstone, procedure changes were implemented at Oyster Creek to assure that waterhammer events would not occur in the ICS piping. GPUN Safety Evaluation SE-315403-005 and Oyster Creek Operating Procedure OP-307 (References 19 and 20) describe the I precautions taken at Oyster Creek to prevent waterhammer, in summary, th-operators are precluded from using the ICS system when the reactor water level is above 180" TAF (top of active fuel). When the water level is above 180" TAF, the possibility exists for reactor coolant in the reactor vessel to enter the ICS steam supply nozzles, it should be noted that on more that, one occurrence, the Oyster Creek reactor vessel level has risen above the ICS steam supply nozzle and there have been no reported instances of waterhammer in the ICS piping. In I addition, the steam supply piping is sloped to allow gravity draining.
These design features combine to produce a system with essentially no dead legs or locations where water can be trapped. Therefore, waterhammer is not expected.
Since there have been no reported waterhammer events in the Oyster Creek ICS piping and no events occurred at other plants after system modifications were made, it is assumed that waterhammer is not a concern for the Oyster Creek ICS piping.
3.3 Fatigue A detailed ASME Code, Section 111, Class 1 piping fatigue analysis was performed to demonstrate that fatigue is not a concern for the ICS piping.
I Details of this calculation are included in Appendix B.
The fatigue analysis considered the stresses in the piping resulting from plant startup and shutdowns (pressure and thermal loads), earthquakes, and also the s' resses due to the thermal transient associated with system 3-3 I
I activation. During normal plant operation, the ICS system is not in operation and sections of the piping, in particular the condensate return piping and the steam supply piping near the condensers, can cool and fill I with condensate. For the thermal transient evaluation, these sections of piping were assumed to undergo a step change in temperature from 70' to 575'F (the system design temperature) on system initiation. The maximum stresses in the pipe wall during this step change transient were used to calculate fatigue usage, in addition, conservative stress intensification factors were used at all locations.
I The ICS system is actuated each plant startup and shutdown, so the stress range used to calculate fatigue usage was the maximum stress range from cold shutdown to hot operation including the effects of system actuation.
A total of 400 cycles (10 cycles / year for 40 years) was assumed. The stresses due to earthquake eventt were also included by assuming 5 occurrences of the Operating Basis Earthquake (OBE) with each occurrence contributing 10 cycles of peak stress. The maximum fatigue usage factors are listed in Table 3.1. As is shown, the usage factors are all very low; the maximum usage fattor is less than 0.2. Thus, fatigue is not a concern for the ICS piping.
I 3.4 Wall Thinning There are two potential concerns with regard to wall thinning of piping and I fittings. These are fabrication wall thinning and service induced wall thinning due to erosion. Fabrication wall thinning can occur during the fabrication of elbows if straight pipe is bent to produce the curved elbow.
This is not a concern for the ICS piping because, to allow for this effect, the elbow piping was ordered thicker than the remainder of the piping, schedule 100 rather than schedule 80. Erosion can also occur in power plant piping which contains liquids or wet steam moving at high velocity.
The ICS piping usually contains saturated steam, saturated liquid, or
. slightly subcooled 1. quid traveling at relatively slow velocities associated with gravity feed. Further, the piping is high chromium I 3-4 I
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stainless steel which is quit <' resistant to erosion or erotion/ corrosion m thinning. Therefore, wall thinning is not a concern.
L 3.5 Creep l
The normal operating temperature of the ICS piping is about 550*f. As J stated in SRP 3.6.3 (Draft), creep is not a concern for austenitic stainless steel operating under 600*f.
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b Table 3.1 MAXIMUM CALCULATED FAllGUE USAGE r _ _ .
Location System (Node) Description Usage A - Condensate C03 8" Pipe Connection to 0.095 Concentric Reducer 002N 8" by 10" 45' Lateral 0.103 Connection to 8" 45' Bend 809 Center of 8" by 10" Lateral 0.093 A - Steam None Calculated (Bounded by B-Steam)
B - Condensate B20 Flued Collar Connection to 10" 0.134 Pipe (With Thermal Gradient)
C28 8" Pipe Connection to 0.174 Condenser Nozzles C01 10" Pipe Connection to Valve 0.133 d (With Thermal Gradient) 008 8" Butt Weld 0.125 l
Cll Center of 8" by 10" Tee 0.143 B - Steam All Flued Cellar Connection to 10" 0.001 Pipe (Without Thermal Gradient)
B01 10" Pipe Connection to Valve 0.001 (Without Thermal Gradient)
B05 Valve Connection to Valve 0.128 B09 10" Valve Connection to 0.002 I Eccentric Reducer 017 12" Pipe Connection to 0.098 Condenser Nozzle l
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I MPR ASSOCIATES. INC.
Section 4 LEAK DETECTION CAPABILITY I
Several methods are available for detecting leaks in the ICS piping outside containment at Oyster Creek. These include (1) visual inspection during system walkdowns, (2) reactor building sump monitoring, (3) area temperature I monitors, (4) area radiation monitors, and (5) building ventilation radiation monitoring. Taken together, these methods provide a high degree of assurance that significant leaks (more than a tenth of a gallon per minute) would be quickly detected, and action could be taken before potentially unstable flaws could develop in the piping.
Since the ICS piping is generally accessible, it is possible to walk the system down to observe possible leakage. According to studies performed by I Wyle Laboratories (Reference 10), visual observations are capable of detecting small leaks. Leaks as small as 0.1 gpm wete seen in the Wyle tests, even with insulated pipe. Currently, operators perform system walkdowns of the ICS piping at least once each day.
Leakage from the ICS piping would condense and would eventually flow into the floor drains. The reactor building floor drains disch?.rge into a single sump (sump #1-7). A daily sump inleakage report is kept by.the operators. This is a log of the volume of water (in gallons) pumped out of the reactor building and other sumps each day. A review of this log for January through May 1990 indicates that the total flow each day is usually less than 250 gallons. A
.g plot of the sump inleakage data for January to May 1990 is shown in
.5 Figure 4-1. From this figure it can be seen that over a typical two day period less than about five hundred gallons are pumped out of the reactor building sump. The pump only actuates when a certain sump level is reached, so it does not necessarily actuate each day. When it does actuate, it l typically pumps 400-450 gallons each time. Typically, the pump actuates every 1I I
I two or three days. The daily log alarm set point is 260 gallons per day, which, if exceeded, requires the operators to identify and document the source l of leakage. For example, a copy of the report for May 20, 1990 is shown in Figure 4-2. This report shows that the hign inleakage for that day, 5,335 gallons, was due to the draining of a water filled line for maintenance, Based on a review of the inleakage report data, it can be concluded that a I leak from the ICS piping exceeding 0.18 gallons per minute (260 gallons per day) would require a daily special leakage evaluation based on the reqctroments of the daily inleakage report. Such a leak (0.18 gpm) in the ICS could not go undetected fo many days, since all of the isolation condenser l piping is accessible for visual inspection.
In addition to the inleakeage report, the reactor building sump has a level switch with a high level setpoint which alarms in the main control room. If a reactor coolant leak were present in the reactor building which exceeded the I sump pump capacity, the sump level would increase and an alarm would occur, indicating to the operators that a problem might exist and appropriate action should be taken.
An area temperature monitor (ATM) is installed near the EC system isolation valves outside containment. This monitor, which has a setpoint of 160*F is capable of detecting leakage in the piping which lies immediately outside containment. Procedure 2000-RAP-3024.01 requires the operators to investigate an ATM alarm and take appropriate actions, including system isolation.
A radiation monitor is included on the reactor building ventilation exhaust, with an alarm setpoint at 13 mR/hr. If a leak developed which contributed to the airborne radiation level in the building atmosphere, this monitor would be able to detect it and the appropriate operator actions could be taken in accordance with procedure EMG-3200.ll.
I In summary, several redundant methods are available for detecting leakage in the reactor building from the ICS and thht operating procedures are in place 4
to address this leakage if it is discovered. Based on sump monitoring and 4-2 I
I I system walkdowns, there are bases to support a detectable leak rate from the ICS piping _of 0.2 gpm.
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l LI 1-7 SUMP DISCHARGE FIGURE 4-1
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l DAILY INLEAKAGE REPORT 5/20/90 WCSUMPS PERIOD 1 PERIOD 2 PERIOD 3 PERIOD 4 PERIODS PERIOD 6 TOTAL eeeeeeee e** e.e ....... e eeeen eeeeeee eesseen eeeeene esese 1-2 0 0 0 22 11 0 33 1-3 0 0 0 0 0 0 0 1-4 0 375 0 0 0 0 375 1-7 940 3270 0 1125 0 0 5335 1-8 423 300 429 412 364 433 2421 1-9 0 0 0 0 0 0 0 1-10 0 0 0 0 0 0 0 1-12 800 424 1154 000 447 593 4219 11RW 1 150 0 0 150 0 ISO 450 NRW 2 900 900 1200 900 1200 900 0000 ilRW 3 0 0 0 0 0 0 0 CHEM LAB 0 0 0 0 0 0 0 LAU11 DRY 0 0 0 0 0 0 0 III CollD 0 0 0 0 0 0 0 ,
TOTAL 3213 5328 2783 3409 2023 2076 18833 l TAllK INC 3500 3780 1120 700 -680 0 8420 llPSUMPS PTRIOD1 PER10D2 PERIOD 3 PERIOD 4 PERIODS PERIOD 6 TOTAL I ........ .
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0 RDEDT 22H 0 0 236 0 464 DWEDT 1132 923 921 1107 915 5901 LOW C0f1D 9 0 0 0 0 0 0 TOTAL 903 1360 923 921 1343 915 6365 TATIK IliC 2188 1360 4494 1194 3792 2236 15264 INVESTIGATE 1-7 SUMP HIGH RUN TIME. NOTE 1 IllVESTIGATE 1-12 SUMP HIG11 RUN TIME. NOTE ?
IliVESTIGATE flRW 1 SUMP llIGil RUN TIME. NOTE 3 IliVESTICATE NRW 2 SUMP llIGH RUN TIME. NOTE 4 NOTE 1 1-7 SUMP-- DRAlflING CONDENSATE LINE NOTE 2: 1-12 SUMP-- CONDENSATE RdTURN TANK OVERTL?W NOTE 3: NRW 1 OUMP-- CONTACTED GPSS. UNABLE TO IDENTIFY SCURCE NOTE di llRW 2 SUMP-- EVAPORATOR AND SUSPECT FLOAT llANCING UP figure 4-2 l
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I MPR ASSOCIATES, INC.
I Section 5 LEAK RATE MODEtlNG I
l The correlation between pipe through-wall crack size and leak rate was calculated using CIRFLO, a specialized computer code developed by MPR specifically for this purpose. The computer model assumes that the pressure l loss through the crack can be described by a typical fL/D loss mechanism.
Choking (critical flow) is evaluated using a homogeneous choking model which I depends on local stagnation pressure and stagnation enthalpy at the choke point. Conservuive, i.e., lower bound, estimates of flow through tight cracks were obtained by using a friction factor based on a relative roughness of 0.1. The crack opening flow area as a function of internal pressure was determined from formulae given in Reference 11. CIRFLO results compare favorably to measured flows through small slits reported in Reference 12 and the LEAKS 01 model developed for EPRI in Reference 13. A more detailed description of CIRFLO, including its technical basis and results of comparisons to test data, is provided in Appendix A.
I The ICS steam supply piping normally r.ontains saturated steam at essentially reactor vessel conditions of 1035 psia, 549'F. The conditions of the fluid in the ICS condensate return piping vary along the length of the pipe from saturated Iiquid at reactor vessel conditions to subcooled liquid at reactor vessel pressure. For the purpose of calculating leak rates from postulated throug:.-wall cracks, the steam suoply and condensate return piping were assumed to contain saturated steam and saturated liquid at normal reactor vessel conditions. This approach, which could underpredict the leakage flow I if the steam supply piping contains water or the condensate return piping is subcooled, is conservative for leak-before-break types of analyses.
The steam supply piping contains six different cross section geometries: 10" diameter schedules 80 and 100,12" diameter schedules 80 and 100, and 16"
> 5-1 I
I diameter schedules 80 and 100, lhe condensate return piping contains four different cross section geometries: 8" diameter schedult; 80 and 100 and 10" diameter schedules 80 and 100. Thus, there are a total of ten pipe size / fluid combinations in the ICS piping. The relationship between through-wall crack length and calculated leakage rate is shown in figures 4.1 and 4.2. These data were used to interpolate the crack sizes required for a leak rate of 2 gpm. The 2 gpm crack sizes are shown in Table 5.1. They range from about 64*
I to 106' of pipe circumference. The detailed calculation of the crack sizes is provided in Appendix A.
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Table 5,1 2 GPM LEAKAGE CIRCUMfEREN11AL CRACK SIZES I -
Piping Fluid Pipe Size 0,c, a 7cm Condensate 1035 psia, 549'F 8" Schedule 80 76* 5.72" Return Saturated Liquid l 8" Schedule 100 86* 6.47" l
10" Schedule 80 64* 6.00" 10" Schedule 100 73* 6.85" Steam Supply 1035 psia, 549'F 10" Schedule 80 93* 8.72" Saturated Steam 10" Schedule 100 106* 9,94" 12" Schedule 80 82* 9.12" 12" Schedule 100 94* 10.46" 16" Schedule 80 70* 9.77" l 16" Schedule 100 80* 11.17" l
3 1
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I Section 6 FRACTURE MECHANICS ANALYSES Analyses were performed to evaluate the likelihood of unstable double-ended pipe rupture in the Oyster Creek ICS piping. This section describes the
.g Leak-Before-Break (LBB) fracture mechanics analyses performed to show that E the probability of postulated double-ended breaks in the piping is very low. The guidelines used for this analysis are taken from SRP 3.6.3 (Draft), Reference 1.
The objectives of the fracture mechanics evaluations, using the guidelines and recommended acceptance criteria presented iti SRP 3.6.3 (Draft) are:
I . Identify the highest loaded locations in the piping system. These are the postulated crack locations. The loading combination considered is I normal operating conditions plus safe shutdown earthquake (SSE) loads.
. For the postulated flaw size determined from leak detection capabilities, show that no unstable failure is predicted for the issumed loading conditions.
Demonstrate a factor of safety in terms of crack length of at least 2.
That is, show that the critical crack length corresponding to unstable I crack growth or tearing of the cracked pipe cross section for the applied load is at least 2 times the postulated crack length.
. Demonstrate a factor of safety in terms of load of at least 1.41.
That is, show that the load corresponding to unstable crack growth or tearing of the cracked pipe cross section for the postulated flaw is at least 1.41 times the applied load.
6-1 I
The ICS piping contains both schedule 80 and schedule 100 thickness for each pipe diameter in the system. However, the installation procedures for the piping allowed the installer to counterbore the schedule 100 piping to schedule 80 diment. ions where necessary to meet fit-up requirements.
Consequently, all fracture mechanics calculations used the schedule 80 wall thickness for the schedule 100 piping. The only exception to this approach was the 10" piping in the steam supply lines. The installer was not permitted tn machine the 10" schedule 100 steam supply piping below schedule 100 limits. For this piping, the actual schedule 100 wall l thickness was used.
6.1 Applied Loads SRP 3.6.3 (Draft) recommends that the loading combination used in the analyses include pipe deadweight, normal pipe internal pressure, normal thermal expansion loads, and safe shutc;own earthquake (SSE). While the ANSI /ASME B3.1 stress analysis models included all of the ICS piping inside
~
and outside containment, the fracture mechanics analyses considered only the piping between the containment penetrations and condenser nozzles.
I This is because the stiffness of the penetrations was found by analysis to be very high; the penetrations are essentially fixed anchors. The portion ,
of the piping outside containment represents the analyzable portion of the system and is evaluated in accordance with the guidance in SRP 3.6.3 IDraft). I The loads on the ICS piping due to the deadweight plus thermal plus SSE i combination are documented in the design stress analysis reports for the piping (References 6 to 9). These loads were calculated using the AUT0 PIPE I finite element program as part of the ANSI /ASME B31.1 evaluation of the piping. The stresses due to internal pressure were determined by hand calculation.
The fracture mechanics methodology described below requires the postulated load on the cracked section to be expressed in terms of an equivalent applied bending moment rather than individual stress components. Fracture 6-2 I
i
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mechanics evaluations are required to be performed at the locations of highest loading in the ICS piping. These locations were determined by calculating the equivalent moment at each node point in the finite element I models of the piping and selecting the highest loaded node for each pipe size in each of the four piping runs (condenser A steam supply and condensate return and condenser B steam supply and condensate return). The method used to determine the equivalent moments is described in detail in Appendix C and is summarized below.
. The loads calculated by AUT0 PIPE at each node point are forces and moments about three axes. The forces and moments at each node point for the deadweight plus thermal plus SSE load combination were I combined using square-root-sum of-squares (SRSS) to determine the maximum force and moment. The calculations in References 6 to 9 provide two sets of results for this load combination: deadweight plus thermal plus SSE and deadweight plus thermal minus SSE. The combination which yields the highest equivalent moment is used.
. The SRSS force is divided by the cross sectional area to calculate an axial stress. The SRSS moment, pipe radius and area moment of inertia are used to calculate a bending stress.
. The axial stress and bending stress from the AUTOPipE results are summed along with the axial internal pressure stress to Jetermine a total equivalent stress at each node point.
. The equivalent moment used in fracture mechanics evaluations is g calculated as the bending moment which would result in the total equivalent stress if only bending stresses were present.
I . The location of highest equivalent moment for each pipe size for each piping system are selected as postclated crack locations.
The points of highest equivalent stress in each system along with the equivalent stresses and moments are shown in Table 6.1. The locations of 6-3 I
f
I these points within the system are also listed in Table 6.1 and are shown on system isometrics in Figures 6.1 to 6.4. As expected, most of the highest stressed locations are either terminal ends of piping, reducers, or drywell penetration attachments.
6.2 Fracture Mechanics Methodology Elastic-plastic fracture mechanics analyses were performed for the normal I operating conditions plus SSE load combination described above to evaluate the margins available for unstable crack growth or tearing at each postulated crack location. The methodology used is discussed below and described in detail in Reference 14.
I An important criteria of the SRP 3.6.3 (Draft) guidelines is that the postulated cracked section should not tear unstably under the applied load.
The cracked section resistance to unstable growth or tearing is determined by examining the moment carried by the crack and mathematically perturbing I the assumed flaw size. Paris, in Reference 15, states that stability is assured if the moment lost from the cracked section due to an increase in crack length is less than the moment that is picked up by the piping system via the increase in cracked section hinge angle. A stable condition is represented by:
I crack < system The expression on the right is a function of the piping geometry and can be evaluated directly from stiffness calculations of the piping system or a finite element model of the piping system by inserting a ball and socket joint at the crack location, applying a moment couple on the joint, and determining the resulting rotations. In Paris' notation, this is the piping system compliance. This system compliance is often equated to the stiffness of a cantilever beam of length, L, with the same area moment of 6-4 I
I inertia, 1, and radius, R, of the pipe. The ratio, L/R, of the equivalent cantilevered pipe is used to report system compliances (inverse of stiffness) in this analysis.
For the widely applicable case where the crack growth and hinge angle are controlled by the J-integral, the expression on the left of the stability equation can be evaluated in terms of the partial derivatives of the J-integral, J, and hinge angle, 4, with respect to crack size, a, and applied moment, M, and a material property called the tearing modulus which is defined as:
E dJ T,y =,
T,u is determined directly from the slope of J vs Aa obtained from test data for the material of interest. In terms of these parameters, the stability criterion becomes (as shown in Reference 14).
I E SJ BJ 2[ 04 -l I T,n > 3 -t O
o a H a +7 a where C, is the system compliance. The expression on the right side of the inequality is commonly referred to as (he applied tearino modulus.
Since the expressions on the right side of the above inequality are all functions of the ratio M/Mo, actual margins to tearing instability can be directly calculated in terms of applied moment and assumed crack size. The application of this stability criterion to cracked pipes is described in I Appendix D.
6.3 Material Properties The ICS pipe material is Type 316NG stainless steel. For this analysis, I lower bound tensile properties for Type 304 stainless steel, which is similar to 316HG, were used. Large strain stress-strain data for Type 304 6-5 I
f
I stainless steel at elevated temperatures are available in Reference 16.
The material strain hardening exponent and coefficient for a Ramberg-Osgood power law strain hardening model, o and n, were determined from these data.
The data base used to define T,y was obtained from cast stainless steel material test data at 550*f reported in Reference 17. Cast material, which is similar to stainless steel weld metal, has lower crack initiation and growth resistance than the pipe base material, thus providing a I conservative lower bound estimate for T,y. Appendix E describes in greater detail the determination of material properties.
The material property values used in the fracture mechanics analyses are presented in Table 6.2. The tensile properties are based upon ASME Code minimum values except for yield strength, where the value taken is that of the material in Reference 16 whose strain hardening behavior was quantified. The flow stress used in limit load analyses was chosen as three times the material design stress intensity value from the ASME Code as recommended in Reference 18.
6.4 System Compliance The methodology developed above to evaluate the stability of postulated pipe cracks requires knowledge of the piping system compliance at each postulated cracked section. The compliance is a measure of how much load is picked up by the piping system as the cracked section sheds moment. In a very compliant system, as the crack grows, the system picks up very l little of the moment on the cracked section, so the load on the section changes very little. In a very noncompliant system, the system can pick up I a large portion of tne moment, so as the crack grows, the load on the cracked section reduces.
The compliance of the piping system at the postulated crack locations was determined using the AUT0 PIPE finite element models of the piping arrangement. For each postulated crack location, a node is added to the system model coincident with the node at the postulated crack location.
The translational degrees of freedom of the two nodes were coupled but the
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I rotational degrees of freedom were uncoupled. Equal and opposite moments were applied on each of the coincident nodes and the resulting rotations determined. This procedure represents the insertion of a ball and socket joint into the model at the postulated crack location. A second analysis was also performed, applying the moments about an axis perpendicular to the first moment to obtain the compliance about two axes. The maximum (conservative) compliance about any axis was obtained using these compliances and a Mohr's Circle approach as recommended in Reference 15.
The calculated system compliances for each postulated crack location are shown in Table 6.3 and ratige from L/R = 38 to 151. Typically, L/R values less than 100 describe a piping system which is fairly rigid; L/R valves over about 150-200 describe a f airly flexible system. Since local I counterboring of the pipe wall (for fit-up) would not significantly affect the overall stiffness of the piping system, all compliance calculations used the actual pipe minimum wall thicknesses (i.e., schedule 100 thicknesses were used for schedule 100 piping). Compliance calculations for the ICS piping are described in more detail in Appendix f.
6.5 fracture Mechanics Results Tearing stability calculations were performed to demonstrate sufficient margin against unstable growth or tearing of the postulated cracks under the applied loads. Calculations were carried out using the piping system I compliance at the postulated crack locations. The results of these analyses, shown in Table 6.4, show that all postulated crack.; are stable under the applied load. All calculated values of the applied tearing I modulus are less than I m. The tearing modulus calculations are described in detail in Appendix G.
As recommended by SRP 3.6.3 (Draft), safety margins in terms of crack size and applied load were determined for each postulated crack location. The safety margin in terms of crack size is the ratio of the crack size corresponding to failure for the applied load to the postulated crack size and is recommended to be at least 2.0. The margin in terms of load is the ratio of the load corresponding to failure for the postulated crack length 6-7 I
B
I to the applied load and is recommended to be at least 1.41. The failure mode is limited by either unstable tearing or plastic collapse of the remaining cross section. Which mode of failure is actually limiting is I dependent on crack size, applied loads, complaince and other factors. In this analysis, margins are reported for each analysis location for whichever failure mode is limiting, unstable tearing or plastic collapse.
As can be seen in Table 6.5, the safety margins in terms of load are all greater than 1.41. It should be noted that in each case evaluated, as the applied load is increased, plastic collapse of the cracked pipe section is controlling rather than unstable growth or tearing. Thus, the safety margin in terms of applied load is simply the ratio of the limit moment I corresponding to plastic collapse for the cracked section to the applied moment.
Table 6.5 also shows safety margin in terms of crack size. In each case, the limiting failure mode is also plastic collapse. As shown in Table 6.5, some of the analysis locations do not quite meet the SRP 3.6.3 recomrnended criteria of a margin of two on crack size (the worst case is 1.75). The safety margin of two on crack size is recommended to account for I uncertaintie- in the fracture mechanics analyses methodology and leak detection capability (Reference 21). ilowever, a factor of 10 has already been applied on the leakage detection capability (when determining crack size) to account for the leak detection and leak calculation uncertainty.
Further, in each case, critical crack size is limited by plastic collapse, which can be calculated relatively precisely compared to a tearing instability limit crack size. Thus, the recommended f actor of two is very tonservative for the ICS piping. Considering the basis for the recommended margin of two, the calculated margins (minimum of 1.75) are considered to provide adequate safety margin again.. failure.
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6-8 .
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I lablo 6.1 HIGil[51 LOADED LOCATIONS Equivalent Equiva location Stress Moment System (Node) Description _ Pipe Size (Ksi) (in Kip) _
A Condensate 004N Elbow 8" Scheduie 80 11.6 284 D03A ,
1 B" Schedule 100 11.6 284 C08 Pipe Weld 10" Schedule 80 9.E 437 i B01 Pipe to Valve 10" Schedule 100_ 8.9 404 _
A Steam B09 Valve to Eccentric 10" Schedule 80 12.0 546 Reducer B01 Pipc to Valve 10" Schedule 100 12.0 640 012 C0ndenser Nozzle !?" Schedule 80 13.6 1017 D10A Elbow 12" Schedule 100 12.3 919 bl9 Pipe Weld 16" Schedule b; 7.1 1025 Bil Snubber Attachment 16" Schedule 100 7.2 1043 B Condensate CM Condenser Nozzle 8" Schedule 80 19.2 470 C26A Elbow 8" Schedule 100 18.0 441 C05 Valve to Pipe 10" Schedule 80 9.8 449
'E B20 'lued Co.- 10" Schedule 1 0 11.3 513 5 Connectt B-Steam B09 Valve to Eccentric 10" Schedule 80 15.7 715 Reducer B01 Pipe to Valve 10" Schedule 100 13.6 724 D17 Condenser Nozzle 12" Schedule 80 14.4 1077 004 Pipe Weld 12" Scheoule 100 13.1 976
,15N Elbow 16* Schedule 80 9.9 1429 B13 Snubber Attachment 16" Schedule 100 10.0 1444 6-9
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Table 6.2 i mal [ RIAL PROP [R1'.[S Property Value @ 550'l Clastic Modulus, [ 25600.0 ksi Yield Stress, o, 23.0 ksi flow Stress, o, 50.7 ksi T, 182 a 2.13 n 3.79 I
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E Tat le 6.3 CALCULA1[D SYS1[M COMPLIANCE
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I System location (Node) Pipe Size l/R A - Condensate 004N 8" Schedule 80 127 D03A 8" Schedule 100 146 B08 10" Schedule 80 127 I A Steam B01 B09 10" Schedule 100 10" Schedule 80 73 38 B01 10" Schedule 100 44 D12 12" Schedule 80 88 D10A 12" Schedule 100 .151 B19 16" Schedule 80 135 Bll 16" Schedule 100 133 B Condensate C28 8" Schedule 80 65 C26A 8" Schedule 100 150 C05 10" Schedule 80 66 B20 10" Schedule 100 65 B Steam 809 10" Schedule 80 39 B01 10" Schedule 100 41 017 12" Schedule 80 124 000 12" Schedule 100 104 315N 16" Schedule 80 104 813 16" Schedule 100 127 8
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I Table 6.4 1
l CALCULATED APPLIED TEARING H0DULUS RISULTS Applied Location learing
'I System (Node) Pipe Sire Modulus
- A Cordensate D04N 8" Schedule 80 1.8 D03A 8" Schedule 100 2.3 B08 10" Schedule 80 0.7 B01 10" Schedule 100 0.7 A - Steam B09 10" 5thedule 80 2.8 801 10" Schedule 100 3.5 D12 12" Schedule 80 3.6 l D10A 12" Schedule 100 16" Schedule 80 4.4 B19 0.4 Bil 16" Schedule 100 0.5 B - Condensate C28 8" Schedule 80 8.9 C26A 8" Schedule 100 11.9 C05 10" Schedule 80 0.8 820 10" Schedule 100 1.4 B - Steam B09 10" Schedule 80 5.9 l
B01 10" Schedule 100 4.6 017 12" Schedule 80 4.7 004 12" Schedule 100 5.1 B15N 16" Schedule 80 0.9 813 16" Schedule 100 1.2
- To be compared to the limiting tearing modulus.1, = 181.
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lable 6.5 SAf[1Y FAC10R5 I Safety Safety location factor on factor on I System (Hode) Pipe Size Applied load Crack length A - Condensate D04N 8" Schedule 80 3.83 2.56 l
003A 8" Schedule 100 3.54 2.26 B08 10" Schedule 80 5.05 3.20 001 10" Schedule 100 5.12 2.86 A - Steam B09 10" Schedule 80 3.23 2.07 B01 10" Schedule 100 2.90 1.82 D12 12" Schedule 80 3.10 2.24 l 010A 12" Schedule 100 3.11 2.02 B19 16" Schedule 80 6.53 3.16 011 16" Schedule 100 5.95 2.75 B Condensate C28 8" Schedule 80 2.32 2.10 C26A 8" Schedule 100 2.28 1.91 C05 10" Schedule 80 4.91 3.17 B20 10" Schedule 100 4.03 2.68 B Steam 809 10" Schedule 80 2.47 1.87 801 10 Schedule 100 2.57 1.75 D17 12" Schedule 80 2.92 2.19 004 12" Schedule 100 2.93 1.98 Bl5N 16" Schedule 80 4.69 2.91 013 16" Schedule 100 4.30 2.54 I
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Section 7 I REFER [t4CES
- 1. Standard Review Plan 3.6.3 (0raf t), published in Federal Register, Volume S2, Number 107, 8/28/87.
- 2. USNRC NUREG 0313, Rev. 2, " Technical Report on Material Selectton and I Processing Guidelines for BWR Coolant Pressure Boundary Piping," January 1988.
- 3. USNRC NUREG/CR-20S9, " Compilation of Data Concerning known and Suspected I Waterhammer Events in Nuclear Power Plants," [G&G Idaho, May 1982.
- 4. USNRC NUREG/CR 2781, " Evaluation of Waterhammer Events in light Water Reactor Plants," IG&G Idaho, July 1982.
- 5. USNRC NUREG-0927 Rev.1, " Evaluation of Water Hammer Occurrence in Nuclear Power Plants," March 1984.
- 6. MPR 1177, " Isolation Condenser System, Analysis of Modified Piping Configuration, Steam Line to Condenser NE-01-A," Rev.1, february 1991.
- 7. MPR 1178, " Isolation Condenser System, Analysis of Modified Piping Configuration, Condensate Line f rom Condenser NE-01-A," Rev.1, Iebruary 1991.
- 8. MPR 1179, " Isolation Condenser System, Analysis of Modified Piping Configuration, Steam Line to Condenser N[-01 0," Rev. 1, february 1991.
- 9. MPR - 1160, " Isolation Condenser System Analysis of Modified Piping Configuration, Steam line f rom Condenser NE-01-0," Rev.1, february 1991.
- 10. NSAC-110. " Leak Detection in Nuclear Piping Outside Containment," Wyle Laboratories, March 1987.
- 11. Hiroshi lada, "The Eficcts of Shell Correlations on Stress Intensity Factors and Crack Opening Area of a Circumferential and a longitudinal I Through-Crack in a Pipe," NUREG/CR-3464, September 1983.
- 12. USNRC NUREG/CR-3475, " Critical Discharge of initially Subcooled Water through Slits," September 1983,
- 13. EPRI NP 3395, " Calculation of leak Rates Through Cracks in Pipes and lubes," December 1983.
5 7-1 5
I I 14. J.E. Nestell and R.N. Coward, " Crack Growth Instability in Piping Systems with Compiex loading,* Nonlinear _EracluttlicGtl401CILVg1pmtll_;.
ElA111C_f3MilCJ1E1MH, AS1H S1P 995, American Society f or letting and Materials, 1989.
- 15. Paul C. Paris, Hiroshi lada, and Richard Marcek, *lracture Proof Design and Analysis of Nuclear Piping," NURIG/CR 3464 September 1983,
- 16. Aerospace Structural Metals Handbook, Volume 2. Code 1303, p. 13.
I 17. J. P. Gudas and D. R. Anderson, "J R Curve Characteristics of Piping Material and Welds," 9th Water Reactor Safety Research Information Meeting, October 29, 1981.
- 18. IPRI NP 2472 SY, Volume 1, "1be Growth and Stability of Stress Corrosion Cracks in large Diameter BWR Piping," July 1982.
I 19. GPUN Safety-[nvironmental Determination and 5D.59 Review, SE-315403 005.
"0ytter Creek Prevention of Isolation Condenser Waterhammer in Oyster Creek Emergency and Abnormal Procedures," October 29, 1986.
- 20. GPUN Oyster Creek Nuclear Generating Station Procedure, OP 307, Rev. 40,
" Isolation Condenser System," October 28, 1990.
- 21. USNRC NUREG-1061, Volume 3,
- Report of the USNRC Piping Review Committee Evaluation of Potential for Pipe Dreaks," November, 1984.
I I
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I OYSTER OREEK NUCLEAR GENERAllNG STA110N
((AK BEFOR,f BREAK EVALVAIJ.ON OF IS0lAT10lj mfd.L!iSLfLSJ11LlLElEIRG OUTSIDE CONTAINMENT MPR - 1226 Volume 11 I
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Prepared for:
General Public Utilities Nuclear Parsippany, NJ April, 1991 I
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- 1. Introduction
- 2. Sunynary & Conclusions E.1 Leak Detection Capability l 2.2 Determination of Detectable flaw Sites 2.3 Applicability of Analysis Method 2.4 fracture Mechanics Analyses
- 3. Applicability of Leak-Before Break Methodoingy l" 3.1 Intergranular Stress Corrosion tracking (IGSCC) 3.2 Waterhammer 3.3 fatigue 3.4 Wall lhinni.ig 1 3.5 Creep
- 4. Leak Detection Capability
- 5. Leak Rate Modelir.g
- 6. fractute Mechanics Analyses 6.1 Applied Loads 6.2 fracture Mechanics Methodology 1 6.3 Material Properties 6.4 System Compliance 6.5 fracture Mechanics Results
- 7. References I mmu1
- 8. Appendices I
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L MPR ASSOCIATES. INC.
Section 8
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SSTORAGEt2 I. PROGRAM CIRFLO C***********************************************************************
C CALCULATES FLOW THROUGM CIRCUMFERENTIAL CRACKS IN PIPES I C VERSION 2.0 10/4/90 C*"*"***"*"******"""""""""****"****"*"""*"*"""""
CHARACTER *1 FF DASH CHARACTER *10 TITLE,ADATE COMMON / TITE / TITLE (8)
COPMON/FRILE/ ROUGH I' DIMENSION PSC(20),TSC(20),V01DC(20)
DATA PI, FACT,GALPP/3.1415926,1A4.0,648.831/
DATA DASM/' */
DAT A PEX/14.7/
DATA RHOW/62.4/
FF= CHAR (12)
CALL DATE(ADATE) -
OPEN(5, FILE ='CIRFLO.INP', STATUS ='OLD')
I OP!N(6, FILE ='C RFLO.0UT',STATU$a' UNKNOWN')
WRITE (*,3000)
WRITE (6,1500) FF,ADATE READ (5,1000) TITLE WRITE (o,2000) TITLE READ (5,1010) N!TER NUMEL,NCRAK, ROUGH I WN= NITER WR I T E ( 6,2010 ) N I T E R . NUME L , N CR AK , R OJGM C
C READ INPUT DATA FOR NEXT PIPE CONFIGURATION )
40 RE AD(5,1020,END=260) 00, THICK,PO,TO,VOIDO,GALMIN,GALMAX,E CRLMIN=GALMIN CRLMAX=GALMAX R*D0/2.0 I C ROT =R/ THICK C DETERMINE INLET THERMC0YNAMIC PROPER!!ES I C X0=VotDo NSSAT=HSV(PO TSAT,$$,VSSAT)
HLSAT=NSL(TSAT)
VLSAT*VSL(TSAT)
IF(VotDO.LE.0.05 *n 10 80
'B IF(VOIDO.GE.1.f; T0=TSAT 10 100 YO=1.0/(VotD0/VSSAT+(1.0 VotDO)/VLSAT)
X0=VO*VotD0/YSSAT N0=K0*HSSAT+(1.0 XC)*HLSAT I GO TO 120 80 CONT!NUE IF(TO.GT.TSAT) T0=iSAT I N0= HCL (PO,TO,$0)
VO=VCL(PO,TC)
C0 TO 120 100 CCWilWUE
,~
IF(TO.LT.TSAT) T0=TSAT
.I H0=HS$(PC,T0,$0,VO) 120 CONTINUE C0=CCTAB(PU,PO,PCRIT)
PO*=P0/145.0 TSP *(TO-TSL(PO))/1.8 I !
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l 1050 Connecticut Ave., NW-Washington, DC 20036 CALCULATON NO. PREPARED BY ECV BY g /(, g / /
PAGE 13 f
I 00G=Go*(39.37/12.0)"2/2.2 WRITE (6,2120)
IF(NCRAK.EO.C) WRITE (6,2030) 1 IF(NCRAK.EQ.0) WRITE (6,2040)
IF(NCRAK.EO.1) WRITE (6,2035)
IF(NCRA8(.EQ.1) WITE(6,2045)
WITE(6,2135) (DASN,Kel,79 WRITr(6,2050) 00, THICK,Po,.' e.ALMIN, GAL ux,E I C WRITE (6,2120)
C DETERMINE APPR0xlMTE C. LACK LENG6 RANGE C
1 $1GCsPO*R/(2.0*TNICK)
CARE A eCR ACKC(1.0,R THICK, s t GC,E )
IF(kCRAK.EQ.1) GOTO 154 GAL C= CAL PP' CARE A *G0/( R MU.l* F 4C T )
CCL1.SQRT(CALMIN/ CALC)
R CCL2*SQRT(GALMAx/ CALC)
GOTO 158 154 CCL1=CRLMIN ,-
CCL2=CdLMAx y
C DETERMINE Flow THROUGH CRACK C
158 CONTINUt WRITE (6,2060)
WRITE (6,2070)
WRITE (6,2130) (DASN,Kai,69)
WRITE (*,3030) 00 240 ful,NN CCL*CCL1+(CCL2 CCL1)* FLOAT (1 1)/tLOAT(NN 1)
CANGLE =CCL/(Pl*DC)*360.0 CAREA*CRACKC(CCL,R,TNICE,5IGC,E)
WCaFLOW(Po,Ho,VO,CCL,CAREA.TNICK,PEx,NUMEL,PSC,TSC.VOIDC.WCC)
GC=0.0 IF(CAREA.NE.0.0) GC= FACT *WC/CAREA C*******
NOTE GPM 15 BASED ON AikYaPMERIC WATER FOR A.KEVP OF SUMP FLOW CALC =GALPP'WC/RMCV GCG=GC*(39.37/12.0)"2/2.2 WRITE (*,3020) CCL,CANGLE.GALC WRITE (6,2080) I,CCL,CANGLE.CAREA,WC PSC(NUMEL),Gtc,GALC 240 CONTINUE WRITE (*,*)
WRITE (6,2120) 60 TO 40 260 CONTINUE CLOSE(5)
CLOSE(6)
$f0P C
C FORMAT:
C 1000 FORMAf g8A10) 1010 FORMAT (315,F10.2) 1020 FORMAT (8F10.2) 1500 FORMAT ( A1,51HCIRFLO CALCULAfl0N OF FLOW THRCUGM CIRCUMFERENTI AL, i 12W PIPE CRACK 3,/1x,12M VER5]DN 2.0,/,1x,14NTODAY'S DATE: ,A10,/)
2000 FORMAT (BA10) 2010 FORMAT (/1x,30wNUMsER OF CRACKS EACH CASE -",15,/1x, 1
30MutteER OF ELEMENT 4 la CRACK -*,15 /1x, 2
30nCRACK FLOW (0) OR LENGIN (1) *,15,/1x,
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3 30HRELATIVE ROUGNutts -""""", F10.5,/)
2020 FORMAf( A1) 2030 FORMA 1 ( 8X ,2HDO,5 X ,5 N T H I CK ,8X ,2MPO,8X ,2M10,5 X 4 HV01 D ,2X ,
18MMIN LEAK,2X,$MMX LE AK,9X,1ME) i 2035 F ORMAf ( 8X ,2NDO,5 X ,5 NI N I CK ,8X ,2HPC,8X ,2N10,5 X 4 HV01 D ,2X ,
18MMIN CRAK,2X,8MMAX CRAK,9X,1ME) 2040 FORMAT (2X,8M(INCHE$),2X ,8M(lNCME $),4X,6M(P$1 A),3X ,7M(DEG F ),10X,
'9H(GAL / MIN),1X,9N(GAL / MIN),5X,5H(P$l))
I 2045 FORMAT (2X,8h(I NCH5$),2X,8M(I NCHES),4X,6H(PS I A),3X,7H(DEG F ),11X, 18M ( I NCME s ),2X ,8M ( I ECWE S ),5X ,5 H ( PS I ) )
2050 FORMA 1(F10.6,710.6,2F10.2,F9.6,2F10.6,F10.0,10X,F10.6,710.2,F10.1) 2060 FORMAf(2X,4Mif ER,5 ,$MCRACK,5*,5 MANGLE,6X,4 MARE A,6X,4MF LW,4X, 1 6MEXIT P,6X.4MFLUX,6X.4hFLOW) 2070 FORMAT (6X,2X,8M(INCHES),2X,8M(DEGREE),3X,7H($Q IN),2X,8N(L5/$EC),
I 1 4X,6M(PSIA),1X,9H(KG/S/K2),1X,9H(GAL / MIN))
2080 F CRMA f ( 16,2 F 10.2, F 10. 3,2 F 10. 2, F 10.1 F 10. 2 )
2120 FORMAT (1X)
I 2130 FORMAf(6X,70A1) 2135 FORMAT (7941) 3000 FORMAT (52N CIRFlo CALCULATION of FLOW THROUGN CIRCUMPERENflAL, 1 12H PIPE CRACK $,/)
I 3020 FORMAT (F10.2,6X,F10.2,8X,710.2) 3030 FORMAT (47H CRACK LENGIN CRACK ANGLE LEAKAGE (GPM)) -
END FUNCil0N CRACKC(CL,R,T StG E)
C************************************************"********************
I C C
c.....C.I DETERMints CRACK AREA FROM GEOMETRY AND STRESS RCLM
. ..... P E.RE CA1A Pl/3.1415926/
N T I AL.CR ACK I
XLaCL/SQRT(R*T)/2.0 I F (XL .L 8. 1. 0) GP = XL **2+0.16*X L"4 I F ( X L . GT .1. 0 ) GP=0. 02+ 0. 81
- X L"2 *0.3* XL"3+0.03* XL"4 CRACKCa$1G'(2.0*Pl*R*T)*GP/E RETURN END FUNCTION FLOW (PO,HO VO,CL CAREA, THICK,PEX,NUMEL.PS,15, VOIDS,WC)
I C**********************************************************************
C JETERMINES THE FLOW 1,lROUGH CRACK INCLUDING FRICTION EFFECf3 C**********************************************************************
I Capetou/FRICR/ ROUGH DIMENSION P$(1),TS(1),V010$(1)
DATA GRAV, FACT,Fil/32.2.144.0,12.0/
DATA CRIT /1.0E 3/
I IF(CAREA.EO.0.0) Co TO 180 DX. THICK /(ifl*F W f(MtmEL))
DN*2.0*CARnA/(CL* Fit's A* CAR 1A/ FACT FINa0.5/(2.0*CRAV' FACT *A**2)
I C C
FOUT *1.0/(2.0* GRAV'F ACT*A"2)
F I N t =0 X/(2.0* GRAV* F ACT
- A"2*D M )
SET LIMITS AND $UPPLY FIRST FLOW GUEb5 I
C WMINsO.0 bMAXs A*GCT A8(PC, HO,PCR I T )
W'(WMI N+6 MAX )/2. 0 C
C SEGIN ITERATIVE LOOP TO Cef AlW FLOW
)
I C 00 140 ITER *1,20 I
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Of fERMINE Fticil0N PRESSURE DROP ON UDE BY Na0E BA515 DO 80 let,NtmEL N5
- HS V(P,15A T ,',, V5 )
I IF(HO.G1.Hl1 GD 10 40 ML*MSL( T S*,s )
I F ( HO . '. s , NL ) GO 10 20 f eTSI ML*NSL(ISA1)
Vt*VSL(15AT)
I Ma(HO-ML)/(H5aHL) vex *Vl*(1.0 X)*VL VOID *X*VS/V I ilSC+V01D*VisV(P,1)*(1.0 votD)*VI$L(P,T)
GO TO 60 20 beS55tCL(P,Ma,T)
VeVCL(P,1)
I VOID =0.0 VISC=VISL(P,T)-
GO TO 60 40 $=st$lt$(P,No,1,V,M)
VolD=1.0 I VitCeVitV(P,T) 60 RE=0N*A85(W)/(A*Vl5C)
C"**" NOTE FOR SMALL CRAOK USE RELAllVE ROUGHNESS OF 0.1 **""*"""
F=FRICTF(RE,1.0,RouM )
I P eP-F
- F IN T *V'W"2 P$(1)*P T5(1)=T V010$(1)= VOID IF(P.LT.PEX) GO TO 120 80 CONF lNUE C CHECK FOR WCROW WIN 10 WAX C
IF(Wik.EQ.0.0) Go TO 100 I C C
C IF(Ass ((WMAX Wik)/WHIN).LT. CRIT) GO to 160 CHECK FGR CRITICAL FLOW OR CRITICAL FLOW CONVERGENCE I
100 WCaA*GCTA8(P,HO,PCRlf)
IF(AS$((WC-W)falC).LT.CR11) GO TO 160 IF(WC.LT.W) GO 10 120 C
C CHFCK FOR NON CRITICAL OUTLET I C P=P 70UT*V*W"2 IF( ASS ((P PEX)/PEX).LT.CRif) GO TO 160 IF(P.LT.PEX) Go TO 1?0 I
C C FLOW !$ 100 LOW
- ADNST ACCORDINGLT l
C WHIN=W W= W+ *AX)/2.0 Go 10 140 C FLOW 100 MIGH - ADJUST Af.CORDINGLY C
I 120 WAX =W t
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C CohVERGED SOLUTION I C 160 FLOWW RETURW 180 FLOW =0.0 RETURN C FORMATS C
I 1000 FORMAT (//13,45HNO CONVERGEhCE IN FLOU EXECVilch TERMINAT;D,/1X, 111 X ,1 HW,8X ,4 HW I N ,8X ,4 HWAX ,11 X ,1 HP, /1 X ,4 E 12. 5 )
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MPR ASSOCIATES, INC. 1050 Connecticut Ave., NW-Washington, DC 20036 CALCULATION NO, PREPARED BY CHECKED BY d h4 N'A b f S efu..m + t_ C I Af6 6 ,.f 9 l Pra 5+ us n ic-n +, f -y , A t tv~ 1. ., s+. e. . :,, & -: ., ts p , a-d us a y Fa < 4 - G leu h is ., 5 l I I I I I I l I
l 5 5 g MPR ASSOCIATES, INC, 3 1050 Connecticut Ave., NW-Washington, DC 20036 CALCULATION NO. PREPARED BY CHECKED BY Y' _ b. 9uf At KhLm l Ap.ns Lecakon : c63 Sy.s k n : A - (on dens a } < bescrop kom : B~ourL p.pt ecureL - le conte., hic odaere InfakJ N $q va h0* (ll) l Po
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tl MPR ASSOCIATES, INC. i' s 1050 Connecticut Ave., NW-Washington, DC 20036 _. j CALCULATON NO. PREPARED BY CHECKED BY S. h.,c d b fc/ 7c G m . - I P, ping S . 4 -ch.ule .s. k t.ocaI.e-:p/<acp3 b es c < tp h e -, B - oke L A in re ' r, r Jo c- N ce-re />a l r e d n r e- ('ren [> t. . d ) l /cs a N r l So = l21,900 pc Fe- ve!< D , 13 14 9 i :i .< :~ is n. n o p, r- cyc u c, i:2 s iv. +~:,+,,, 124,000 f1 t' t ? f !! { , b lb . A NYH i* t in, goo p, c:- ,: &, i. s sty + ~: 1 + ~ esoo r p i. . <y , f , tu. , 4. < ~ l =400 p. i- ;. c i) , i.2 s i:p < m ,- 4 .- I TL va lu .5 l.. y - of a rt u: < A ? <-:e+..,,, Ea:s ac A 1h u i .y fra n < _ E, u = ? ' s s c> pi ,D i?.950 fi: r,,oo p, y; I n,= w s , , , , u,
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I MPR ASSOCIATES, INC. I CALCULATION NO. 1050 Connecticut Ave., NW. Washington, DC 20036 PREPARED BY CHECKED BY b.hAd'L fcl 9clO+w '1 l Pip.us t .- A-(cAe~.n L o c o A: e y.r 6#2 Nh bv I 4s * /a le be:c e sp h e- : 6 <ne; n - i. < i- I ce .-- ,'s-
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Nc 1250 f.s e (c* ryle igv : y f e-A Q O pts f? eyr (< }y< Q) I Mi = l2h312 t - li.: & 140 90 0 1 fe li s' @ i 93,0(e 4 u -lis & l r, = i. c kz = /. o
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'I MPR ASSOCIATES. INC. 1050 Connecticut Ave., NW-Washington, DC 20038 CALCULATON NO. PREPARED BY CHECKED BY O. c6L 'O f.( %fws% g 0.p.3 s, & . u s, . n L a en n < n b n .v h(f C t ofh l:s @
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L MPR ASSOCIATES, INC. - 1050 Connecticut Ave., NW-Washington, DC 20036 CALCULATION NO. PREPARED BY CHECKED BY A. gc. c c &-- . (Dck ' .~ PAGE g - L P>p an Sy rk~ : S.Sko n
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j l5 MPR ASSOCIATES, INC. g 1050 Connecticut Ave., NW-W ,rJ]gton, DC 20036 CALCULATK)N NO. PREPARED BY CHECKED BY g J. b A Cc nh PA E q,g Pipi, Sys k ~ : B -5 h + ~ g Loca vn
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29, 900 p, k <p p @, i . s .c /p k n .z , hs, 23,200 p. k- cyth D , ball uld n, s cc pi h - eye b (f) , N6- 42ro be ui ko, 35,
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[' MPH ASSOCIATES, INC. 1050 Connecticut Ave., NW-Washington, DC 20036 r CALCULATON NO, PREPAHED BY CHECKED BY L
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I MPR ASSOCIATES, INC, 1050 Connecticut Ave., NW-Washington, DC 20036 g CALCULATION NO. PREPARED BY CHECKED BY
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MPR ASSOCIATES, INC. l [, 3 1050 Connecticut Ave., NW-Washington, DC 20036 f ~ ~ > dd%fbN NO.
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B l MPR ASSOCIATES, INC. 1050 Connecticut Ave., NW-Washin0 ton, DC 20030 g cat.CULATON NO, PREPARED BY CHECKED BY 4).t)ac#6' s',t C Cvi~- #* H *
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MPR ASSOCIATES, INC. 1050 Connecticut Ave.. NW-Washington. DC 20036 CALCULATION NO PREPARED DY CHECKED OY (). Quek (,t 9 g u. L ~ H IB P p.m spn : 8 - a~% n l L er n /.<- : C28 be.t c .p h en - 9 aeL e , ,r e e . . . 4, ,. .h er , b ,e , , l n o 17 /c l .T n p a 4.s 4e F_.9 u a L o - (t I )_j ho
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MPR ASSOCIATES, INC. 1050 Connecticut Ave., NW-Washington, DC 20036 CALCULMION NO. PREPARCD BY CHECKED DY
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I ItAR: Calculation of foering Maistus - Version 2.0 I foday's Date: 10/05/90 verification Problem #2 A106 Gr B Carbon Steel tese Metal I track lengt'. (a/b): 125 Pipe Dieneter: 20,000 Irches Pipe Well Thickness: 1.000 trches l l I Atolled Moment: 4278764.0 in Lb Applied Load /Yleld Load: 1,00 Plastic Collapse /fletd Load
- 1,61 System Corylierce (t/R): 500.
Ninge Angles .1 degrees I J integret 1313.1 in Lb/in8 Toering Mockalue 23.2 8 I L
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i litCRAGi t ? PtXR AM 11 At g enese s s e ous a seeseene s e e e e ee e e eeee ee ene essee e e ee e e enes eeee e e eeeeee C , geeeeaeoseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeese ChARAC3tt*10 AtAtt ChAAntitt'50 titti LMARACitt*35 MLAt[L CtneeJu/DAftthf0/ADAft DATA Pl/3.141$9/ CALL DAtt( Anatt) g 20 00kiistit Witt(*,') W I 1((',iD00) W ilt(*,*) W lit (*,2020) ktAD(',1000) Il1Lt W i t t (* ,') CAL L Gt f MA1(ML A2t l.,t .11tL,t 0,Ilcit o, AL, te) CALL GiOM(t,1) 201st/t bel *t Witt(*,*) .e W a t f (* ,2040) et AD(*,1020) A00 W itt(*,*) W i t t (* , t N,0) 1 81AD(*,1070) att W itf(*,2080) ttAD(*,1020) KM 40 C0kilWA lit =Ple(t*'4-(t 1'i**A)/4.0 tePI*t Aet'A00 Cet 4 } GAmAeP l' A00 i CALL GIPt0F(A00,14,801,N),H4,91,V3,N1P,71P,V3P) DN1DAaN1P/t DF10Aef1P/t ov30AeV3P/8 til GaC05(GAmA/2. 0 ) ilk ( GAmA)/2.0 k M0e ? .0* $ 1 GO* t ' A
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Wlit(*,2200) f C iMI!t;",?)60) XJ WitE(',2160) f f ARV Walit(*,') af-furt 1400 8t*Mf(' !! Att Calculation of icerleg mceAatue version 1,0*. i /,1R 1%M 10: ley's Dates , A10,/: , 2NM Km9?(450) 7020 f CueAt(ell) .e 2040 00RM1(' Crack Lergth (a/b): 8,fl.3) 2%0 FCRMT(' Plce Of eneters ',f 6.3,' trwhes') 73fd 80NMitt Pl;* Well thickrees ',f6.3,' irthen') 2100 f >M11' Plett'c Colletse/Y teld LeMr ',f 4.2) 7110 f C*Mf(' Amtied Nwt ',f12.1,' in tb') 2120 f0kMAI(e A m[ged (g dfygggd Lond e,p4,gg 2160 FCmuf(' tystem (capt hwice (L/t): 4 810.0) 2160 F0aM4f(' J* Integral 8,f10,1,' in tb/in) 21hD fotMi(* Tearthe MmAstues ' F 2A f 0PMf(' Ninge Ans t e. ',f 6.k,10.1) ' degrees') (WD tuet0VilWL CECM(t ee e e e e e e e e e e e e e e e e e e e e e s,1,e)e eee e e e e e e e e e..e e e e e e e.e e e e e e e......e e e e e e... C go.eeeeeeeeeeeeeeeeeeeeeeeeeee...eeeee....ee......ee. eeeeeeeeeeeeeeee. Wtift(*,') Wti f t (*,20N)) tiAD(*,10001 0 We 1it (*,2020,i
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C geoeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeesseeeeeeeeeeeeeeeeeeeeeeeeeeeeee CkAeAttte'35 MLAfttt(3),MLAs DATA MLAh!L/* Aib Gr 0 Cartxoi steel Dese mets l', 1
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DATA MA1/3/ W l f f ( *,2000) I 1
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- Goto 100 (WDif 100 Cani1Wut 10=51G0/t
,I ttfusu tND SUBR0lliik( GtPROP( A08,IW,R0f ton eeee eeee eee eee e eee e eeeeeeeeeeeee, h". , N4, F 1, v3, N 1 P , F I P , V3P ) eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeese C C" " " '''" "' " *********************************************** NisNIVAL(Aos,ru,Rof) N4eh4 VAL (A00,XW,R01)
. Fief 1 VAL (A08,RQ1) v3eV3 VAL (WJB,00f)
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C C' " ' " "'****************************************************' "' ' DATA DEL /0.05/ if(Aus.tt.0.125) 1Mth A1'0.0625 l A2e0.125 IWolf if( Ats.ht.0.125. AND. Ace tt.0.25) tut h A1 0.125 l M en.25 tWDIF 1 f ( A00.ht .0.25) 1et e A1 0.25 A2 0.5 twDif Dilet f tvAL( A2, Pot).fiv&Lt A1, tot))/( A2. A1) ettutt two FUNCil0W DV3(Ace, ton) C********" "' "************************************************* C teeeeeeeeee........eeeeeeeeeeeee..............eeeeeeeeeeeeeeeeeeeeeeeee DATA DEL /0.05/ if(Aus.tt.0.125) THth A1 0.0625 A2 0.125 (NDif If( A00.Ct.0.125. AND. Aos tt 0.25) 1>t u A1 0.125 Af=0.25 tuolf if(Ms.ht.0.25) THEW A1 0.25 A2=0.5 ENLif DV3*(V5 VAL ( A2.tof) V3 VAL ( A), A01))/( Al A1) tituth E do PUNC1 g ........10N N1 VAL.(.AS.,tu.t01) J
i MPR ASSOCIATES, ING, 1050 Connecticut Ave., NW-Washington, DC 20036 CALCULATION NO. PREPARED BY 04E 3 / f / / if. L c PAGEAb[Af l . I :...................................................................... Olmtklltes N1(5,4) AB,At(4) AWVAL($),9016 AL(3) D A 1 A N 1/4,96 F,6. 018,6. 743, f.620, F.969, 1 S . 361, $ . V8 F. 6. 261,6. 311,6.906, I 2 3 5.620,5.312,4,686,3.9$9,3.240,
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DATA AlvAL/0.0625,0.125,0.2%,0.$/ Data swv&L/1.0,2.0,3.0,l.0,2.0/ I DAT A 40TWAL/%.0,10.0,20.0/ DAfA hAB,kAN,ht01/4,$,3/ ACg.Ag if( A06.C1. ABVAL(kA8)) A08.ABV AL (h AD) 00 40 1 2, hat if( A00.Lt. Alv&L(1)) TH(k 1 11 1 1 12 1 G0fD 60 INDlf l 40 CChiluut 60 comIluut 00 80 J.2,Wik If(th.Lt.kuvAL(J)) TH(u i J1.J+1 J2.J G010 100 (kDit i 60 ComilWut 100 Cout tkut
'tACA.( AUS ABYAL(11))/( AbvAL(12) AtVAL(11))
f 8 ACh.(EN thv&L(Jt))/(suvAL(.2).NuvAL(J1)) VAL 1.M1(J1,11)*fAACW.(MitJ2,11).W1(J1,II)) i VAL 2.M1(J1,12).f R ACw.(NitJ2,12).M1(41,12)) M1VAlevAli.fRACA.(VAL 2 4AL1) etfuth (W0 i F g . . . . .L.*..C. i .l 0.N ..
....... M4......
V A L .( AB ., t u ,0 01.) . . . . . . . . . . . . . . . . .. . . . . .. . . .. . . . . . . . . . . . . C...................................................................... c DIMikll0N h4(5,4). AuvAL(4),rWVAL($),00f val (3) I 1 2 CA1 A M4/ .194,0.078,0.144,0.268,0.429, 0.136,0.565,0.763,1.119,1.312, 1.459,2.076,2.334,2.3D8,2.049, 3 5.384,=.283,3.232,2.049,1.400/ CAf A ABVAL/0.0625,0.125,0.25,0.5/ CATA RWVAL/1.0,2.0,3.0,$.0,7.0/ DA1A eofyAL/5.0,10.0,20.0/ DATA NAB,uxW,ht01/4,5,3/ A06.A5 If(A06.Gl.AtvAL(kAB)) AOS.ABVAL(NAB) 00 40 1 2.has if( Ace.Lt. A8 VAL (1)) TH(N 11 1 1 12 1 0010 M INDlf 40 CCattwut 60 C% flWut W 60 Jet,Wxu if tXW.Lt.INVAL(J)) f ut u i
. - _ _ _ _ _ _ - - - - _ _ - - - - J
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'At teh4(J1,11)ef t ACW'(>4(J2,11) M4(J1,li))
3 VAlleW4(J1,12) ftACW'(k4(Jt,12) h4(J1,82)) h4VAleVAliefRACA*(VAL 24AL1) Rttute IND F0mC110N fiv&L(AB,tof) _I gneeenesennneeeeeenneeeneen neeseeeesennnn e eeneneene C.ees...e t eeeeeeeeeeee....eeeeeeee. eeeeeeee...e e.....eeeee....e e...e I 1 2 DIMiktlow f1(4,3), ABvAL(4) P0iv4L(3) DATA F1/1.046,1.141,1.423,2.555, 1.0 TO,i .219,1. 5 W,P. 896, 1.118,1.343,1.8%,3.33f/ I DA1A AlvAL/0.0625,0.125,0.25,0.5/
- W A 60iv4 /5.0,10.0,20.0/
DATA hAB,ht01/4,3/ ** AcceAt if( A00.G1. AlvAL(NAI)) AN.AgvAL(WAI) tier 0f Ale 10.0 I DO 40 le2,Wt01 If(RT.L( .t0f VAL (1)) 1Ntt 11 1+1 llel B 0010 60 (NDil 40 CoutlWVE 60 CONilNUt DO 60 Jet,hAB If( ACA.Lt. ABvAL(J)) THth 41es'1 J2e4 0010 100 (NDif 80 Cottluut 100 COWiluut iiAtte( Al 801v&L(li))/(tofvAL(12) 80fvAL(li)) iRACAe(Aos A8vaitJ1))/iAsvAL(JP) AlvAL(J1)) VAliof1(J1,11).f8ACA*(f1(J2,11).f1(J1,11)) VAL 2.f 1(Ji,12).f t ACA*(f 1(J2,12)* f 1(J1,ll)) FivAleVAliettACh*(VAL 2 VAL 1) titute iN0 fuhC110N V3kAL(Al,kOT) C""*"""""*"**"*"**"""*"""""*"""""""**"""*** C geeeeenneeneeennneeneennneeenne eenne e enseenne nn blMikil0W V3(4,3), ABy&L(4),koTVAL(3) DA1 A V3/. 065,0.003.0.389,3.925, 1 *
.043,0,014,0.504,5.112, 2 a.070,0.020,O.626,6.TVS/
DATA ABVAL/0.0625,0.125,0.25,0.5/ DATA ROTVL /5.0.10.0,20.0/ l _,,____.m_ _ _ _ - _ . _ _ . - - - - - - - . -
MPR ASSOCIATES, INC. I CALCULA1CN NO. 1050 Connecticut Ave., NW-War.hington, DC 20036 PREPARED BY C 4E
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AfetOf Ale 10.0 00 A0 lot.ht01 I IF(tt.tt.toival(l)) THit 1111 12=1 0010 60 I iNDlf 60 CokiIwut 60 ConfIwat DO 80 Je2, hat IF(Aug.Lt.AlvAL(J)) fMEN I J1eJ.1 J2*J Golo 100 tWDIF I 60 CONI!WJE 100 COMiIWUE f tAtte(Rf at0fvAL(li))/(tofvAL(ll) tofvAL(11)) f tACA*( A00+ Alv&L(J1))/(AlvAL(J2) A8 VAL (J1)) W Ali s V)( J 1,11 )+ f t ACA'( V3 ( J 2, l i )
- V3 ( J f ,11 ) )
I VAL 2=V3( J1,ll)e f RACA*(V)(J2,ll).V3(J),12)) V3vAlevAL1*fRAtt*(VAL 2 VAL 1) effute iND I I I I I I I I I
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