ML20126F463
| ML20126F463 | |
| Person / Time | |
|---|---|
| Site: | Perry  |
| Issue date: | 06/07/1985 |
| From: | Edelman M CLEVELAND ELECTRIC ILLUMINATING CO. |
| To: | Youngblood B Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 8506170487 | |
| Download: ML20126F463 (174) | |
Text
'
2 P O. Box 5000 - CLEVELAND OHlu 44101 - TELEPHONE (216) 622-9800 - lLLUMINATING BLDo - 55 PUBLIC SOUARE Semng The Best Location in the Nation MURRAY R. EDELMAN VICE PRES 10ENT NUCLE A R June 7, 1985 PY-CEI/NRR-0264 L Mr. B. J. Youngblood, Chief Licensing Branch No. 1 Division of Licensing U. S. Nuclear Regulatory Commission Washington, D.C.
20555 Perry Nuclear Power Plant Docket Nos. 50-440; 50-441 ASME Class 1 Piping Break Locations and Dynamic Effects (SER_ Confirmatory Issue 1)
Dear Mr. Youngblood:
Section 3.6.2 of the Perry SER required that the Final Safety Analysis Report (FSAR) incorporate the results of final piping stress analyses on designated piping systems to determine break locations.
The results of these studies have been incorporated in Perry FSAR Section 3.6, including figures 3.6-71 through 3.6-80, in Amendment 19.
A copy of this information is attached for your reference.
We believe this information is sufficient to resolve Confirm-atory Issue 1 in the next supplement to the Perry SER.
Please call if there are any questions.
Very truly yours,
%%4 O
Murray R. Edelman Vice President Nuclear Group MREtnjc Attachment cct Jay Silberg, Esq.
John Stefano (2) 0 01 J. Grobe
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n through 3.6-47, systems and components required for safe shutdown are protected from postulated pipe rupture, to a large extent, by physical arrangement.
Detailed descriptions of these physical arrangements are presented in j
Sections 3.6.1.2.1 and 3.6.1.2.2.
3.6.1.2.1 Physical Arrangement Inside the Reactor Building a.
Inside the Drywell
.To the greatest possible extent, the piping, the electrical, and structural arrangement within the drywell provides for safe shutdown capability in the event of high energy pipe rupture by means of spatial separation.
Both the main coolant piping (recirculation and feedwater) and the ECCS piping are
+
evenly distributed around the reactor.
Furthermore, the electrical power divisions serving the various ECCS systems govern the location of system i
pipe routing to prevent any single high energy pipe break from jeopardizing
-any additional ECCS. A limited number of postulated ruptures could potentially jeopardize the functioning of an adequately redundant number of ECCS due to limitations bf spatial and barrier separation.
Each such case j
is discussed in Section 3.6.2.5.3 and resolved either by means of a jet shield or by analytically establishing the adequacy of separation. These high energy lines within the drywell are restrained from whipping by elastic / plastic pipe whip restraints which prevent pipe whip damage to essential systems and limit structural loads.
b.
Between the Drywell and the Reactor Building Wall Between the drywell and the reactor building wall, portions of two high
, energy systems constitute potential pipe rupture sources:
the reactor water cleanup system and control rod drive supply line.
In all cases postulated ruptures are located so that spatial separation provides protection to ECCS
- -from the effects of postulated ruptures.
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a High energy lines between the drywell and the reactor building wall are
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restrained from whipping by pipe whip restraints in all cases in which damage could have occurred to structures, systems or components necessary for safe shutdown.
3.6.1.2.2 Physical Arrangement Outside the Reactor Building Building arrangements outside the reactor building are characterized by the following areas for purposes of the pipe rupture analysis:
a.
Inside the Steam Tunnel A significant design feature of the plant with regard to postulated rupture of high energy piping is the provision of the steam tunnel. This structure serves as a conduit for essentially all high energy piping between the reactor building and turbine building. The steam tunnel is designed to contain the environmental effects (pressure and temperature) resulting from a full circumferential pipe break (double ended rupture) of either a main steam or feedwater pipe. Following such a postulated event, the steam tunnel vents the blowdown from the break to the turbine building. Rapid closing isolation valves close to limit the release of mass and energy from the break. These valves and their operation are discussed in Sections 5.4.5 and 6.2.4.
The pressure rise analysis for this design basis event is discussed in Section 3.6.2.2.
A description of the structural design and analysis of the steam tunnel is presented in Section 3.6.2.3.
High energy piping rauted through the steam tunnel is shown in Figure 3.6-24.
Pipe whip restraints are provided to prevent consequential damage following a postulated pipe break.
b.
Inside the Fuel Handling Building The fuel handling building is free of high energy lines, except for one 2 1/2-inch nominal OD control rod drive (CRD) line which conveys cold water at approximately 1900 psig. This line is prevented from damaging surrounding structures by means of piping supports 3.6-3 Am. 19 (5-13-85)
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of sufficient capacity. No equipment required for safe shutdown is located in the vicinity of the route of this line in the lowest elevation of the fuel i
j' handling building. The consequences of a postulated rupture of this line are i
limited to local flooding of the lowest elevation in the fuel handling building to a depth of approximately 6 inches.
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c.
Inside the Intermediate Building i
The intermediate building contains no high energy piping.
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j Moderate energy lines whose failure could result in limited (less than 6 inches in depth) flooding of the lowest level of the intermediate building 4
i present no hazard to the operation of any systems essential to safe plant shutdown.
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l Inside the Auxiliary Building d.
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The auxiliary building, excluding the structurally separated steam tunnel addressed in Item a, above, contains four sources of high energy pipe ruptures. The reactor water cleanup system piping and pumps are located in i
a compartment which is vented to a corridor containing safety related l
electrical cabling. Analysis of the conditions following the pipe rupture event indicate the safe shutdown capability of the plant is not jeopardized.
The second source of high energy pipe rupture occurs in a main steam drain line routed through the same corri, dor which communicated with the RWCU pump room. The piping configuration of this drain line is such that the postulated break occurs within a guard pipe which vents also to the steam tur.nei. Analysis of the effects of this event indicate the safe shutdown i
capability of the plant.is not jeopardized A third source of high energy pipe rupture is the RCIC steam drain in the RHR room "A".
This line f
' operates atilow flow and pressure and presents no significant hazard. The fourth source of high energy pipe rupture is the auxiliary steam system.
The main auxiliary steam piping is routed over-the auxiliary building roof, and enters chrough the steam tunnel roof.
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i Two 10 inch RCIC-RHR condensing cooling mode steam lines pressurized from n
, U the reactor vessel are located in two RHR heat exchanger rooms. A four inch branch to the RCIC turbine is located in the RHR "A" room. However, an orifice is included in the system design which restricts the amount of energy escaping from a full rupture of these lines. The orifice is sized to assure that safe plant shutdown is not jeopardized by temperature or environmental effects. Shields and restraints provide required protection from transient jet and rupture loads.
e.
Inside the Control Complex The control complex is isolated from adjacent structures by 3-foot thick concrete walls and pressure tight doors where required.
A portion of moderate energy piping is concentrated in two areas of the control complex. One area, at elevation 599'-0", houses the nuclear closed cooling water (NCCW) heat exchangers served by service water piping. The piping and heat exchangers are in a single, enclosed room. Water flowing from a postulated leakage crack in NCCW or service water piping would either drain through sleeves in the floor to the next lower elevation at 574'-10" or discharge directly into that elevation. The area below the NCCW heat exchanger room at elevation 574'-10" houses the service and instrument air receiver tanks. Elsewhere at this elevation are essential shutdown systems.
The water would drain to the floor of this space and from there to floor drain sumps equipped with safety related instrumentation that actuates alarms upon detection of high level.
O 3.6-5 Am. 19 (5-13-85)
l The maximum leakage rate is from a through-the-wall crack in service water piping, and is calculated to be 1.9 ft3/sec.
Pipe size is 42 inches, nominal OD, with a wall thickness of 1/2 inch, and a system head of 52 psi.
This piping is seismi ally supported. This leakage rate would flood elevation 574'-10" to a depth of 2 inches in 27 minutes, at which time the high water level would also be alarmed by flood level detectors, in addition to those provided in the sumps. Considering the inventory of isoittable sections of service water piping, an additional 8 minutes is avail 4ble for a total a 15 minutes from first sump level alarm to required isolation in order to t nient c final flood in excess of 6 inches.
Equipment required for safe shutdown or for maintaining control room habitability is located at elevation 574'-10".
This equipment includes three water chillers and the emergency closed cooling water pumps. This equipment is protected from flooding by mounting it on 6-inch foundation pads.
The area at elevation 679'-6" above the control room houses chilled water piping (CCCW) that provides cooling for the control room HVAC equipment.
This is moderate energy piping. This area also houses a 140 kw electric boiler capable of producing 480 lb/hr of saturated steam at 5 psig. This boiler supplies a low pressure humidification system, whose piping is defined as high energy piping.
An analysis of possible effects of jets and pipe whip due to humidification system breaks shows that safe shutdown is not jeopardized. The low power rating of the boiler and the small energy reservoir of the system preclude any rapid environmental effects. Redundant leak detection sensors are provided to assure that any failure is detected with ample time to shut off the boiler before environmental effects could compromise safe shutdown Components.
The maximum leakage rate from a postulated moderate energy crack in the CCCW pipe is calculated to be 168 gpm. The pipe size is 10 inches, nominal OD, with a wall thickness of 0.365 inches, and a system head of 130 feet.
The area at elevation 679'-6" is sealed off from the control room and is 7(O provided with completely embedded drain piping sized to carry water issuing from the design basis leakage crack to drain sumps outside the control i
complex.
3.6-6 Am. 19 (5-13-85)
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f.
Inside the Radwaste Building O
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The radwaste building contains a high energy steam line that supplies steam l
to the radwaste evaporators. This line is routed outside the radwaste l
i building and enters the building, directly into the radwaste evaporator room, through the roof.
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There is no equipment, piping, electrical cable, etc., in or routed through
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the radwaste building that is required for safe shutdown.
g.
Inside the Diesel Generator Building Only moderate energy piping is located in the diesel generator building.
Each diesel generator is separated from adjacent diesel generators by
'8-inch thick concrete walls. Therefore, any postulated event that might disable one diesel generator is prevented from adversely affecting the others.
h.
Yard Piping and Other Structures Piping failures in yard piping and in piping in structures not addressed in Items a through g, above, have been found to result in conditions that do not jeopardize safe plant shutdown or adversely affect operation of safe shutdown systems.
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3.6.1.3 Safety Evaluation Failures which could affect the ability to bring the plant to a safe shutdown condition are analyzed in Chapter 15. These analyses include consideration of the occurrence of a single active component failure in required systems coincident with postulated pipe rupture. The pipe rupture analysis clearly demonstrates that no system or component required for safe plant shutdown is rendered inoperable as a consequence of any postulated pipe rupture.
3.6.2 DETERMINATION OF BREAK LOCATIONS AND DYNAMIC EFFECTS ASSOCIATED WITH THE POSTULATED RUPTURE OF PIPING Pipe break and crack location criteria and methods of analysis are needed to evaluate the dynamic effects associated with postulated breaks and cracks in high and moderate energy fluid system piping inside and outside of primary
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3.6-7 Am. 19 (5-13-85)
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L 2.
For ASME Code,Section III Class I, Seismic I piping, breaks are postulated to occur at intermediate locations between terminal ends whenever the following stress and fatigue limits are exceeded:
(a) The maximum stress range between any two load sets (including the 3
zero load set) shall be calculated according to equation (10) of article NB-3653 of the ASME Code,Section III for normal and upset plant conditions, including safety relief valve (SRV) loads, and an operating basis earthquake (OBE) event transient. If this value is less than 2.4 Sm, no break need be postulated.
i (b) If equation (10) exceeds 2.4 Sm but is less than 3.0 Sm and the I
cumulative usage factor U of article NB-3653.5 is less than 0.1, no break need be postulated.
1 (c) If for a given load set, equation (10) exceeds 3.0 Se, but the 4
maximum stress ranges calculated accord'ing to equations (12) and I
(13) of article NB-3653.6 for that load set are each less than O
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a t" t tt
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article NB-3653.6 (using equation (14) or article NS-3653.3 for S,tt) does not exceed 0.1, no break need be postulated.
j In accordance with article NB-3653.6 and BTP-MEB 3.1, Section B.1.b.(1)(b), equations (12) and (13) need be evaluated only for 4
those load sets for which equation (10) exceeds 3.0 Sm.
I A list of Class 1 analysis nodes where the cumulative usage factor exceeds 0.1 or where either equation (12) or (13) exceed 2.4 Sm is provided in Table 3.6-18.
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3.
For ASME Code,Section III class 2 and 3 piping, breaks are postulated l
to occur at all locations where the sum of equations (9) and (10) of ASME Code Section III, article NC-3652, calculated under all normal and
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l upset plant conditions, including safety relief valve (SRV) loads, and
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an independent operating basis earthquake (OBE) event transient, is greater than 0.8 (1.2 Sh + S ), except that the more restrictive A
j criteria of Sections 3.6.2.1.7 and 3.6.2.1.8 apply to containment penetration piping.
3.6-11 Am. 19 (5-13-85)
d.
Circumferential breaks are assumed at all terminal ends and at intermediate locations identified by the criteria stated in Section 3.6.2.1.5.
At each of the postulated break locations identified, in piping four inches nominal diameter or greater, either a circumferential or a longitudinal break, or both, is postulated according to the following criteria. " Maximum stress j
range" is calculated as described in Sections 3.6.2.1.5.a.2.a and 3.6.2.1.5.a.3.
f 1.
If the maximum stress range exceeds the limit of Sections 3.6.2.1.5.a.2.a or 3.6.2.1.5.a.3 and the maximum stress range in the longitudinal direction is greater thaa 1.5 times the maximum stress i
range in the circumferential direction, only the circumferential break I
need be postulated.
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2.
If the maximum stress range exceeds the limit of Sections 3.6.2.1.5.a.2.a or 3.6.2.1.5.a.3 and the maximum stress range in the t
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circumferential direction is greater than 1.5 times the maximum stress t
j range in the longitudinat direction, only the longitudinal break need be postulated.
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i 3.
If the maximum circumferential and longitudinal stress ranges are within a factor of 1.5 of each other, or if the analysis does not differentiate between circumferential and longitudinal strest ranges, then both types of breaks are postulated.
i 4.
Circumferential breaks are postulated at fitting joints.
5.
Longitudinal breaks are postulated in the center of the fitting at two
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l diametrically opposed points (but not concurrently) located so that the l
l reaction force is perpendicular to the plane of the piping and produces out-of plane bending.
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6.
At intermediate locations where stress ranges are less than the criteria of Sections 3.6.2.1.5.a.2 and 3.6.2.1.5.a.3, and breaks are l
chosen to satisfy the criteria for a minimum number of break locations, I
l only circumferential breaks are postulated in accordance with f
BTP,MEB 3.1, B.3.b(2)(b).
3.6-13 Am. 19 (5-13-85) i
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3.6.2.1.7 Criteria for High Energy Piping Systems in the Area of f
Containment Isolation Valves i
3.6.2.1.7.1 Locations for Postulated Breaks j
i No pipe break is postulated in the portions of high-energy piping in the containment penetration break exclusion region.
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The containment penetration break exclusion region is defined as that section of i
ptptng between (1) the outboard weld of the outboard containment isolation valve 3
and (2) the inboard weld of the inboard containment isolation valve. Where a
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torsional and moment restraint is required to meet the containment penetration stress criteria under rupture loads, and where breaks between the containment l
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l Isolation valve and the restraint would also cause these criteria to be exceeded, l
the containment penetration break exclusion region is extended to the restraint.
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The break exclusion regions of major high-energy lines are indicated on l
Figures 3.6-5, 3.6-6 and 3.6-7.
No safe-shutdown components other than containment isolation valves and their auxiliaries are located in break exclu,isn j
regions.
3 4
1 The containment penetration region of high energy piping meets the following t
criteria for break exclusion regions:
i.
a.
For High-Energy ASME Code,Section III, Class 1 Piping:
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1.
Piping in this region shall meet the requirements of article NE-1120 of the Code.
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2.
The stress criteria of Section 3.6.2.1.5.a.2, shall not be exceeded.
I 3.
The maximum stress in the break exclusion region due to a postulated rupture of the affected line outside the break exclusion region, as j
calculated by equation (9) of article NB-3653 of the Code, shall not iO i
l 3.6-15 an. 19 (5-13-85)
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exceed 2.25 Sm, except that following a failure outside contain=ent
,3 higher stresses are allowed between the outboard contain=ent isolatien valve and the outbcard torsional and oc ent restraint, provided a plastic hinge is nct formed and the operability of the valve is assured under this loading in accordance with Standard Review Plan 3.9.3.
Primary loads for equation (9) include those loads which are deflection-Linited by restraints.
For most piping systems the B, B2 indices are taken from Table t
NS-3633.2-1 from the ASME Code, SIII 1974 Editien, W'75 Addenda (Design code of record). For sone butt velding elbcws, the Bg, B2 indices used are taken fron the equivalent Table NS-3631(a)-1 frcs the 1930 Edition. W'81 Addenda of the ASME code. This addenda acknowledged that internal pressure does not detract from the me=ent carrying capacity of elbows. This is especially relevant for a pipe rupture analysis.
A 10 ptrcent increase to allowabic stress is per=itted reflecting the
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10 percent increase of "nini=um specified design yield strength" (Sy) due to strain rate effects.
b.
For High-Energy ASME Ccde,Section III, Class 2 piping:
1.
Piping in this region shall meet the requirements of article NE-1120 of the Code.
2.
The stress criteria of Section 3.6.2.1.5.a.3 shall be =et.
3.
The =axi=um stress in the break exclusion region due to a postulated rupture of the affected line outside the break exclusica region, as calculated by equation (9) of Article NC-3652 of the Code, shall not exceed 1.8 Sh.
The exceptions permitted for Class 1 piping under Section 3.6.2.1.7.1.a.(3), above, may be applied to piping outboard of the outboard contairment isolation valve, provided that any such piping between the valve and outboard torsional and so=ent restraint
(
t) 3.6-154 Am. 19 (5-13-85)
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g constructed to the ANSI B31.1 power piping code shall be provided with
'd full radiography of all welds, both circumferential and longitudinal.
Primary loads for equation (9) include those loads which are deflection-limited by restraints.
For most piping systems the "i" stress intensifiers given in Figure NC-3673.2(b)1, (ASME code; SIII, 1974 edition, W'74 addenda) are used. A number of components, primarily tapered transitions, are evaluated using equation 9 of NC-3653 and the B, B2 indices of NB-3680 t
of the 1980 edition, W'81 addenda of subsection NC of the ASME code.
This addenda acknowledged that the "i" factor is not an appropriate factor for most components for the evaluation of primary loads such as due to pipe rupture.
A 10 percent increase to the allowable stress is permitted reflecting the 10 percent increase of " minimum specified design yield strength" (Sy) due to strain rate effects.
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O For both Class 1 and Class 2 piping, the design and inspection requirements c.
stated in Sections 3.6.2.1.7.2 through 3.6.2.1.7.5 are satisfied.
3.6.2.1.7.2 Welded Attachments to the Process Pipe Welded attachments, for pipe supports or other purposes, to these portions of piping are designed by means of detailed stress analyses to demonstrate compliance with the limits of Sections 3.6.2.1.7.1 a and b.
A typical attachment is a welded lug for torsional and moment restraints.
In addition, the number of circumferential and longitudinal piping welds are minimized. There are no branch connections in these portions of the process pipe, with the exception of the RHR-RWCU connections to the feedwater lines in the steam tunnel, and drains and vents. Where guard pipes are used, the enclosed portion of fluid system piping is of seamless construction. The length of these portions of piping is the minimum practical. The analysis of the head fitting, including the welds to the main steam pipe and the guard pipe, is in accordance with the CE report NEDO-23652.
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3.6.2.1.7.3 Design of Pipe
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- Pipe anchors are designed to be 100 percent volumetrically examinable in service e
and a detailed stress analysis is performed to demonstrate compliance with the l
2 limits stated in Section 3.6.2.1.5.
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3.6.2.1.7.4 Cuard Pipe Design m,'J)
Design criteria for guard pipe assembly are as follows:
a.
Construction requirements satisfy Subsection NE of Section III of the ASME Code.
b.
The guard pipe is designed to a temperature and pressure equal to or greater than the normal operating temperature and pressure of the process pipe.
c.
The guard pipe is pressure tested in accordance with SA-530-5 of the ASME Code, either by the materials manufacturer or the guard pipe fabricator.
This test may be performed prior to fabrication of the complete assembly.
d.
A 100 percent volumetric examination is performed in accordance with the V
requirements of the ASME Code,Section III, Subsection NE, for all longitudinal welds (Category A) and all circumferential welds (Category B) in the guard pipe.
e.
A 100 percent volumetric examination is performed in accordance with the requirements of the ASME Code,Section III, Subsection NB or NC, depending upon class, for the head fitting to process pipe weld as a full penetration Category C weld.
3.6.2.1.7.5 Augmented In-Service Inspection Augmented volumetric inservice inspection for high energy piping systems in the containment penetration break exclusion is described in Section 5.2.4.9.
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j 3.6-16 Am. 19 (5-13-85)
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3.6.2.1.8 Criteria for Moderate Energy Piping Systems in the Area of Containment Isolation Valves No through-wall leakage cracks are postulated in the portions of* moderate-energy piping between containment isolation valves which meet the following criteria a.
The requirements of article NE-1120 of the ASME Code,Section III.
b.
The maximum stress range calculated as the sum of equations (9) and (10) of article NC-3642 of the ASME Code, section III, under normal and upset plant conditions including safety relief valve (SRV) discharge loads, and an operating base earthquake (OBE) event transient, does not exceed 0.4 (1.2 Sh + S )*
A Where an approved design allows placement of both isolation valves on the same j
side of containment, the piping between containment isolation valves shall be l
taken to include the pipe extending from the valves to the veld defining the I
Class 2 to Class MC boundary.
- O 3.6.2.2 Analytical Methods to Define Blowdown Forcing Functions and Response Models i
3.6.2.2.1 Analytical Methods to Define Blowdown Forcing Functions Rupture of a pressurized pipe causes the flow characteristics of the system to change, creating reaction forces which can dynamically excite the piping system.
The reaction forces are a function of time and space and depend upon fluid state 3.6-16a Am. 19 (5-13-85)
c.
Safe shutdown of the plant following postulated pipe rupture in the reactor coolant pressure boundary must not be aggravated by sequential failures of safety related piping and required ECCS performance must be maintained.
d.
Offsite dose limits specified in 10 CFR 100 must be met.
e.
Postulated design basis breaks resulting in jet impingement loads are assumed to occur in high energy lines at full (100 percent) power operation of the plant.
l 4
f.
Through wall leakage cracks are postulated to occur in moderate energy lines j
and are assumed to result in wetting and spraying of safety related structures, systems, and components.
1 g.
Reflected jets are considered only when there is an obvious reflecting surface (such as flat plate) which directs the jet onto a safety related i
I target. Only the first reflection is considered in evaluating potential i
targets.
!O Jet impingement loads are calculated using the following assumptionst For N555 piping systems, the direction of the fluid jet for purposes of a.
determining impingement loads is based upon the position of the pipe during steady state blowdown. In BOP piping systems, for purposes of determining i
the direction of the fluid jet for impingement loads, circumferential breaks are assumed to result in pipe severance and separation amounting to at least one diameter lateral displacement of the ruptured piping sections unless physically limited by piping restraints, structural members, or piping 1
stiffness, as may be demonstrated by inelastic limit analysis.
j b.
The impinging jet proceeds along a straight path.
t The total impingement force acting upon any cross sectional area of the jet c.
is time and distance invariant, with a total magnitude equivalent to the fluid blowdown force as defined below.
. O 3.6-23 Am. 19 (5-13-85)
d.
The jet impingement force is uniformly dirtributed across the cross sectional area of the jet and only the portion intercepted by the target is considered.
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3.6-23.
Am. 19 (5-13-s5)
e.
The break opening is assumed to be a circular orifice of cross sectional flow area equal to the effective flow area of the break.
f.
The jet impingement force is equal to the steady state value of the fluid blowdown force as calculated using the methods described in Section 3.6.2.2.1.
l g.
The distance of jet travel is divided into two or three regions. Region 1 (see Figure 3.6-50) extends from the break to the asymptotic area. Within I
this region the discharging fluid flashes and undergoes expansion from the break area pressure to atmospheric pressure.
In region 2 the jet remains at a constant diameter. For partial separation circumferential breaks the area increases as the jet expands. Therefore, it is assumed that region 3 never l
occurs. In region 3 (except in partist separation circumferential breaks) l interaction with the surrounding environment is assumed to start and the jet expands at a half angle of 10 degrees.
h.
Moody (6) has developed a simple analytical model for estimating the asymptotic jet area for steam, saturated water and steam-water blowdown conditions. For fluids discharging from a break and which are below the I
saturation temperature at the corresponding room pressure or have a pressure l
l at the break area equal to the room pressure, expansion does not occur.
l L.
The distance downstream from the break where the asymptotic area is reached (region 1) has been found by Moody (for circumferential and longitudinal l
breaks) to be approximately equal to five pipe diameters. Assuming a linear 1
I expansion from the break area to the asymptotic area, the jet shape can be defined for region 1, as well as for regions 2 and 3.
Figure 3.6-51 is used to determine the asymptotic area.
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3.6-24 Am. 19 (5-13-85)
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m.
For the partial separation circumferential break described in Item k, above, the target loads are calculated in a similar manner, except that the jet cross section appears as shown by part (8) of Figure 3.6-50 and AR equals Ax and DA equals M and is calculated in accordance with Item k.7, above.
Evaluation of the ability of potential targets to withstand the jet impingement loads is performed using the following methodst i
s.
Evaluation of Piping Systems under Jet Impingea nt Loads 1.
General Electric piping systemst (a) The stresses due to jet lapingement loads on piping are considered primary stress and are evaluated using ASME Code Section III limits for Service Level D.
1 i
(b) The motion of piping due to jet impingement loads is limited by J
structural steel, pipe whip restraints, snubbers or other equipment capable of providing support. This effect is accounted for in the analysis.
2.
Balance-of plant piping systemst Jet impinsement loads on piping are considered emergency or faulted i
loads and are evaluated as primary stresses in ASME Code Section III piping analyses.
Level C or D service limits are used.
Functional check calculations are performed for piping whose function is required for the given event.
3.
Each jet impingement load is applied independently to the piping system and the load which supplies the largest bending moment for each particular component is used for the evaluations of the pressure retaining capability or functionality of that component.
- O 3.6-29 Am. 19 (5-13-85)
(b) Static Load Portion
,_.s
/
i V
The static load portion of the impingement is combined arithmetically with other simultaneous loads by the absolute sum method.
c.
Evaluation of Jet Impingement Loads on Mechanical System Components 1.
The physical configuration of valves, pumps, etc., is approximated by rectangular and cylindrical solid shapes enveloping the component elements for the purposes of determining angular deflection coefficients and shape factors.
2.
Loads are considered to be part of piping or structural loads due to jet impingement, according to the physical arrangement of the target.
Moments are included in the piping loads for jet impingement on valve operators where a compon6nt of the valve loading is normal to the pipe axis.
O N
d.
Evaluation of Jet Impingement Loads on Electrical Cable Trays The only safety related electrical cable trays subject to impingement by high energy jets are located in the RWCU heat exchanger rooms inside containment and the l' nit 1 RCIC pump room outside containment. The trays in the RWCU pump room are fully protected by jet shields. The tray in the RCIC pump room contains RCIC and RCIC room leakage detection circuits only, which are not required to survive the postulated breaks, since the equipment in the rooms is assumed to be lost as a result of the postulated break.
e.
Evaluation of Jet Impingement Loads on Electrical Conduit and Instrumentation Inpulse Lines The design criteria for routing of electrical conduit and instrument impulse lines is intended te ensure that impingement by high energy jets does not O
3.6-31 Am. 19 (5-13-85)
occur. However, this is not always feasible. Support of conduit and impulse lines subject to jet lapinsement is established by adjustments to spacing criteria which assure conduit integrity under governing load conditions. Design of special supports for rigid conduit and routings of j
flexible connections to equipment consider individual load conditions from l
Impacting jets. Jet shields are used to protect against jet impinsement if protection by support design and by routing is not feasible. Circuits not required for safe shutdown for a given pipe break do not require protection.
- O l
L I
1 O
3.6-314 Am.19 (5-13-as)
I In both units, the Service Water piping is routed above the 599'-0" floor gV elevation. This piping is of 24" nominal diameter in Unit 1 and of 42" nominal diameter in Unit 2.
This pipe has been supported to Seismic Category I.
However, the need to postulate a through-wall crack remains.
391 and 916 gallons per minute, in Units 1 and 2 respectively, will exit the crack and flood elevation 599'-0".
In addition, there is approximately 13,600 ft.3 of water available to drain through the crack siter shutdown of the service water pumps.
3
!.imiting the inventory to 13,600 ft.3 requires that the nearest valves, up and down stream, in all branches be closed.
In order to mitigate the effects of such a flood, the following has been implemented i
Curbs on elevation 599'-0", will keep the fLcod from flowing to elevation 568'-4".
Shields will be installed to assure that jets from the
, ervice water piping will not spray over these curbs. These shields are s
installed only for the length of pipe adjacent to the curbs.
An 8" drain is installed at elevation 599'-0" of Unit 1 and 2 Auxiliary Buildings. In Unit 1, the drain is in the northwest corner.
In Unit 2, the drain is in the southwest corner. This drain is routed down, through the elevation 574'-10" floor deck and ir.to the Auxiliary Building Condensate Domineraliser Room pipe chase.
In this chase there exists an 8" underdrain. The underdrain is fed by seven small sumps and discharges into the Condensate Demineraliser room sump. Using Unit 2 as a scenario and taking no credit for flow into the condensate demineralizer room sump, a leak may continue at 916 spm for 50 minutes. Tils time will be sufficient to isolate the crack, and assure the operability of essential components within the area.
O 3.6-45a Am. 19 (5-13-85) l
3.6.2.5 Material to be Submitted for the Operating License Review 3.6.2.5.1 Implementation of Criteria for Pipe Break and Crack Location and Orientation 3.6.2.5.1.1 Postulated Pipe Breaks in Main Steam Piping System, Including Reactor Core Isolation Cooling Piping - Inside Containment The criteria for selection of postulated pipe breaks in the main steam piping system inside containment are presented in Section 3.6.2.1.
Postulated pipe break locations and types selected in accordance with these criteria for main steam lines A through D are shown by Figure 3.6-65.
Conformance with these criteria is demonstrated by Table 3.6-7.
l l
For each line, no breaks are postulated in that portion of the main steam piping near the containment isolation valves in accordance with the criteria stated in l
Section 3.6.2.1.7.
Conformance with these criteria is demonstrated by Table 3.6-8.
3.6.2.5.1.2 Postulated Pipe Breaks in Recirculation Piping System, Including Residual Heat Removal Piping - Inside Containment The criteria for selection of postulated pipe breaks in the recirculation piping system inside containment are presented in Section 3.6.2.1.
Postulated pipe break locations and types selected in accordance with these criteria are shown by Figure 3.6-66 and 3.6-66a.
Conformance with these criteria is demonstrated by Table 3.6-9.
3.6.2.5.1.3 Postulated Pipe Breaks in Feedwater Piping System - Inside Containment The criteria for selection of postulated pipe breaks in the feedwater piping system inside containment are presented in Section 3.6.2.1.
Postulated pipe j
break locations and types selected in accordance with these criteria are shown by Figure 3.6-67.
Conformance with these criteria is demonstrated by Table 3.6-10.
n m
3.6-47 Am. 19 ($-13-85)
P i
3 3.6.2.5.1.4 Postulated Pi;e Breaks in Emergency Core Cooling Piping l s,)
System - Inside Containment l
The criteria for selection of postulated pipe breaks in the ECCS piping systen I
instde containment are presented in Section 3.6.2.1.
Postulated pipe break l
locations and types selected in accordance with these criteria are she.n by
{
Figures 3.6-68, 3.6-694, and 3.6-69b.
Conformance with these criteria is l
descastrated by Table 3.6-11.
i i
t 3.6.2.5.1.5 Postulated Pipe areaks for Other Piping Systems - Inside Containment The criteria for selection of postulated pipe breaks in other high energy piping systems inside containment are presented in Section 3.6.2.1.
Postulated break locations and types selected in accordance with these criteria are shown by Figures 3.6-70 through 3.6-74 for the RCIC head spray, CRD supply line, R'4CU system, and main steam drains, respectively.
t I ()
Small high-energy piping may be assumed to break at each veld and fitting and
? \\-)
l each terminal end. Review of the jet ispact and pipe whip hazards is then done on this basis. If protection from breaks at every such location is not 1
practical, the stress analysis is reviewed to the break Iccation criteria of I
section 3.6.2.1.5.1, and breaks are postulated accordingly.
Restraints, shields, and other measures necessary to assare safe shutdewn in the event of each postulated break are provided, regardless of the criterion by which the break was postulated.
d 1.6.2.5.1.6 Postulated Pipe Sreaks for Piping Syste=s - Outside Containment The criteria for selection of postulated pipe breaks in high energy piping systems outside containment are presented in Section 3.6.2.1.
Postulated break locations and types selected in accordance with these criteria are shown by Figures 3.6-70s and 3.6-75 through 3.6-80.
I i
3.6-48 Am. 19 (5-13-45)
l I
i Small high-energy piping may be assumed to break at each weld and fitting and each terminal end. Review of the jet impact and pipe whip hazards is then done I
on this basis.
If protection from breaks at every such location is not practical, the stress analysis is reviewed to the break location criteria of Section 3.6.2.1.5.1, and breaks are postulated accordingly.
l Restraints, shleids, and other esasures necessary to assure safe shutdown in the l
f event of each postulated break are provided, regardless of the criterion by which the break was postulated.
I O
I t
I t
I I
i l
i.
l i
I l
O l
3.6-48a Am. 19 (5-13-85) i l
i
- -. - _. - - ~_ -. _ ~ -
t l
l I
[
3.6.2.5.2.2 Pipe Whip Restraints for Recirculation Piping System, Including Residual Heat Removal Piping - Inside Containment Pipe whip restraints provided for the recirculation system piping are shown by Figure 3.6-66 and 3.6-66a.
This system of restraints has been found to prevent unrestrained pipe whip resulting from a postulated rupture at any of the identified break locations.
3.6.2.5.2.3 Pipe Whip Restraints for Feedwater Piping System - Inside Containment 1
l 1
Pipe whip restraints provided for the feedwater piping system inside containment are shown by Figure 3.6-67.
This system of restraints has been found to prevent unrestrained pipe whip resulting from a postulated rupture at any of the identified break locations.
I 3.6.2.5.2.4 Pipe Whip Restraints for Emergency Core Cooling Piping l
System - Inside Containment i
Pipe whip restraints provided for the ECCS piping system inside containment are i
shown by Figures 3.6-68, 3.6-69a, and 3.6-69b.
This system of restraints has t
been found to prevent unrestrained pipe whip resulting from a postulated rupture at any of the identified break locations.
3.6.2.5.2.5 Pipe Whip Restraints for other High Energy Piping Systems -
Inside Containment l
Pipe whip restraints are provided for other high energy piping systems inside containment, to prevent unrestrained pipe whip resulting from a postulated rupture at any of the identified break locations.
i
'O 3.6-49 Am. 19 (5-13-85)
(C 3.6.2.5.2.6 Pipe Whip Restraints for High Energy Piping Systems - Outside v
Containment l
Pipe whip restraints provided for main steam and feedwater piping systems outside containment in the safety related steam tunnel area of the auxiliary building are j
shown by Figure 3.6-24.
These restraints have been found to prevent unrestrained pipe whip in the vicinity of safety related structures, systems, and components resulting from a postulated rupture at any of the identified break locations.
Pipe whip restraints are provided for other high energy systems (other than main steam and feedwater) in the steam tunnel and auxiliary building to prevent l
unrestrained pipe whip which would jeopardize safety ralated structures, systems, and components. The system has been found to prevent unrestrained pipe whip resulting from a postulated pipe rupture at any of the identified break i
locations.
3.6.2.5.3 Summary of Results of Jet Effects Analysis l p lV 3.6.2.5.3.1 Jet Effects for Postulated Ruptures of Main Steam Piping System - Inside Containment i
1 Fluid jet thrust for each of the postulated break locations in the main steam piping are listed in Table 3.6-12.
Structures, systems, or components essential to safe shutdown of the plant in the case of a particular pipe break and subject to impact by the steam jet from the particular break are discussed in the l
following paragraphs a.
liigh Pressure Core Spray Injection Pipe Integrity of the llPCS is required only to assure that the essential line, in this case LPCI B, is not subjected to either a direct main steam jet or impact by a failed flPCS pipe. Figure 3.6-81 illustrates the physical arrangement and impact loads.
' O V
3.6-50 Am. 19 (5-13-85)
l l
b.
Standby Liquid Control System Injection Line Aziumth 2400 l
,.J The standby liquid control system is required to assure the capability to achieve less than k=1.0 reactivity, at cold shutdown conditions. in the event of failure of control rod drives.
c.
Low Pressure Core Injection, Line A (LPCI A) Azimuth 450 The LPCI A line is required for a main steam break plus loss of offsite f
power plus loss of Division II diesel.
The main steam jet impact loads noted in Items a, b and c above, are resolved as l
followsI High Pressure Core Spray injection Pipe a.
The impact on the HPCS pipe of a jet from the ruptured main steam line was analysed as both an impact load and as a steady state load in combination O
with thermat, deadweight, and seismic loads acting on the pipe simultaneously. At no time was the maximum allowable stress exceeded at any point in the impacted HPCS pip!ng run.
b.
Standby Llquid Control System Injection Line Asimuth 2400 Shields were provided to protect this Llne from the effects of main steam breaks.
t c.
Low Pressure Core Injection Line A (LPCI A) Azimuth 450 i
Analysis of the LPCI A line under the postulated loading shows that faulted limits are not exceeded.
k I
i 3.6-51 Am.'19 (5-13-85)
t
/
3.6.2.5.3.2 Jet Effects for Postulated Ruptures of Re' irculation Piping c
(.)
System - Inside Containment Fluid jet thrusts for each of the postulated break locations in the recirculation piping system are listed in Table 3.6-13.
Structures, systems, or components essential to safe plant shutdown in the case of a particular pipe break and subject to impact by the steam jet from the particular break are discussed in the following paragraphs:
a.
High Pressure Core Spray Piping Figure 3.6-84 illustrates the physical arrangement, impact loads and jet shields.
b.
Control Rod Drive Bundles - Longitudinal Break Similar jets from four different postulated recirculation line breaks could impact any of the four CRD bundles at reactor pressure vessel azimuths 740, 1060, 2540 or 2860 Figure 3.6-85 illustrates the physical arrangement and O
impact loads and jet shields.
l The recirculation line jet impact loads noted in Items a and b, above, are resolved as follows:
l a.
High Pressure Core Spray Piping The impact on HPCS pipe of a jet from a ruptured recirculation discharge header was analyzed as both an impact load and as a steady state load in combination with thermal, deadweight, and seismic loads acting on the pipe simultaneously. At no time was the maximum allowable stress exceeded at any point in'the impacted HPCS piping run.
Shields have also been provided to intercept these jets at the source.
b.
Control Red Drive Bundles - Circumferential Break A circumferential break in the recirculation discharge header connection at any of four locations, 600, 1200, 2400, or 3000, was found to result in a
's-
- jet impact that caused overstress of individual withdraw lines and exceeded
~-
'.. s-3.6-52 Am. 19 (5-13-85) sw
~,
w
the design capacity of the entire impacted CRD tube bundle supports if a jet
(
shield were supported from the bundle. Jet shields are provided to intercept these jets at the source to prevent over stress of individual withdraw pipes or tube bundle supports as a result of the postulated event.
3.6.2.5.3.3 Jet Effects for Postulated Ruptures of Feedwater Piping System - Inside Containment Fluid jet thrusts for each of the postulated break locations in the feedwater piping system are listed in Table 3.6-14.
Structures, systems, or components essential to safe shutdown of the plant in the case of a particular pipe break and which are jeopardized by the jet resulting from a particular break are discussed in the following paragraphs:
a.
Control Rod Drive Bundles at Reactor Pressure Vessel Azimuths 740 and 2860 A jet shield is provided around the CRD bundle arrangement to prevent overstress of individual withdraw lines or tube bundle supports as a result
(}
of the postulated event.
l O
l l
3.6-53 Am. 19 (5-13-85) l l
2 i
A jet shield for the CRD bundle at azimuth 740 protects against a feedwater
()
loop A rupturel a shield for the CRD bundle at azimuth 2860, against a loop B rupture.
t b.
Low Pressure Core Injection B Piping Jet impact loading on LPCI B piping and valve operator was analyzed both as an impact load and as a steady state load in combination with thermal, deadweight, and seismic loads acting simultaneously. At no time was the maximum allowable stress exceeded at any point in the impacted LPCI B piping.
3.6.2.5.3.4 Jet Effects for Postulated Ruptures of Emergency Core Cooling Piping System - Inside Containment 4
Fluid jet thrusts for each of the postulated break locations in the ECCS piping system are listed in Table 3.6-15, Structures, systems, or components essential to safe plant shutdown in the case of a particular pipe break and which are jeopardized by the jet resulting from a particular break are discussed in the following paragraphs:
High Pressure Core Spray Pipe a.
HPCS piping is subject to jet impact resulting from postulated rupture of LPCI B piping. Both the HPCS isolation valve and pipe support elements add to the total load resulting from jet impingement. Figure 3.6-90 illustrates physical arrangement, impact loads and jet shields.
b.
Low Pressure Core Injection B Pipe LPCI B piping is subject to jet impact resulting from postulated rupture of HPCS piping. The LPCI piping, isolation valve, and pipe supports are struck by the conically expanding jet as shown by Figure 3.6-91 which illustrates physical-arrangement, impact loads and jet shields.
l O
3.6-54 Am. 19 (5-13-85) i r.
~. _,. _ _.
., - ~ _. *,,.
c.
Automatic Depressurization System (ADS) Valves, Air Lines and Accumulators.
Longitudinal breaks at the valve welds and upper elbows could cause jet impact loading on the ADS valves, or their air lines and accumulators, sufficient to compromise the required ADS capacity for the break size.
1 l
i a
O
.J
-L a
O 3.6-54a Am. 19 (5-13-85)
The ECCS line jet impact loads noted in Items a and b, above, are resolved as
'g%
r follows:
a.
High Pressure Core Spray Pipe Jet impact loading on the HPCS piping was analyzed both as an impact load and as a steady state load in combination with thermal, deadweight, and seismic loads acting simultaneously. Jet shields were provided to intercept these jets at the source, if the maximum allowable stress was exceeded at any point in the impacted HPCS piping.
b.
Low Pressure Core Injection B Pipe Jet impact loading on the LPCI B piping was analyzed both as an impact load and as a steady state load in combination with thermal, deadweight, and seismic loads acting simultaneously. Jet shields were provided to intercept these jets at the source, if the maximum allowable stress was exceeded at any point in the impacted LPCI B piping.
- O c.
Automatic Depressurization System (ADS) Valves, Air Lines, and Accumulators.
Shields were provided to intercept these jets at the source.
3.6.2.5.3.5 Jet Effects f' rom Postulated Ruptures of Piping Systems -
Outside Containment Fluid jet thrusts for each of the postulated high energy pipe breaks outside containment are listed in Table 3.6-16 Structures, systems, or components essential to ssfe plant shutdown in the case of a particular pipe break and which could potentially be jeopardized by the jet resulting from a particular break are discussed in the following paragraphs:
a.
Shield Building Wall A short term dynamic loading of the portion of the shield building wall forming the end wall of the auxiliary building steam tunnel results from the j
l 3.6-55 Am. 19 (5-13-85) l l
-...- =.
postulated full circumferential rupture of a main steam line outside the f
outermost moment and torsion limiting restraint. The turbine side of such a rupture is an unrestrained whipping pipe located within a nonsafety category structure, the steam tunnel. Motion of the whipping pipe is such that, for l
i j
i 9
E i
5 4
4 t
O 1
r 4
i P
e i
1-O 3.6-55a Am. 19.(5-13-85) t i
.-,,-,,r-,
..+-.
aw
- + - +., - - -
g v
e, +..
,e--e--,c n-+,<
e
-+
.,~m,,-
a portion of its movemant, the jet strikes the shield building. Figure 3.6-92
()
shows the approximate physical arrangement and the area struck by the jet at the position of maximum impact. Duration of the jet impact is less than 100 msec and the shape of the force-time curve is approximately sinusoidal.
b.
Main Steam Isolation Valve Should any one of the four main steam lines rupture immediately outside the outer pipe whip restraint, the outer main steam isolation valve in the affected main steam line or in an adjacent line may be impacted by the resulting jet. A short duration impact, similar to the load time history described in Item a, above, results from the whipping motion of the broken pipe as it rises above the normal pipe centerline. Figure 3.6-92 illustrates the approximate physical arrangement for a typical break and the loads involved.
O C) 3.6-56 Am. 19 (5-13-85)
The jet impact loads noted in Items a and b, above, are resolved as follows:
a.
Shield Building Wall Dynamic loading of the shield building wall was analyzed in conjunction with other thermal, deadweight, and seismic loads acting simultaneously. The loading was found to be within the capacity of the structure.
b.
Main Steam Isolation Valve Dynamic loading of a main steam isolation valve was analyzed as a steady state maximum loading and was superimposed on the equivalent thermal, deadweight, and seismic loads acting on both the valve elements and the piping system. Resultant component and pipe stresses were found to be acceptable.
O oV 3.6-57 Am. 19 (5-13-85)
r TABLE 3.6-1 HICH ENERCY LINES (1)(2)
System Number System Designation B-21 Main Steam - inside containnent (SRV discharge piping excluded)
N-11 Main Steca - outside containment N-27 Feedwater System B-33 Recirculation System N-22 Main Steam System Drains - including RCIC steam drain E-51 Reactor Core Isolation Cooling System - steam supply from main steam line "A" out to E51-M0F045 and E12-M0F052 E-51 RCIC Head Spray - from RPV to E51-A0F066 C-33 Reactor Water Cleanup System C-36 RWCU Filter /Demineralizer System E-12 Low Pressure Core Injection Loops "A", "B" and "C" (RHR) - from RPV to E12-F041A, B & C E-21 Low Pressure Core Spray - from RPV to E21-F006 l
E-22 High Pressure Core Spray - from RPV to E22-F005 C-11 Control Rod Drive Hydraulic System - Pump discharge side only C-41 Standby Liquid Control Supply Line - from RPV to C41-F007 B-21 RPV Head Vent to Main Steam Line "A" P-61 Auxiliary Steam System M-29 Control and Computer Room Humidification System E-12 Normal Shutdown - (from connection to the B33 System to E12-F009 and return from E12-F053 to the connection to the N27 System)
E-32 MSIV Leakage Control - (to first normally closed isolation valve.)
NOTE:
1.
Fluid _ systems that, during normal plant conditions, are either in operation or maintained pressurized under conditions where either or both of the following are met:
maximum operating temperature exceeds 2000F, or a.
b.
maximum operating pressure exceeds 275 psig 2.
High energy lines that are located in the turbine building, yard, or other areas free from safety related equipment and structures are not included in this list.
3.6-59 Am. 19 (5-13-85) 1
Q
%.)
TABLE 3.6-5 COMPARISON OF PDA AND NUCLEAR SERVICES CORPORATION CODE RESTRAINT PERCENT OF DESICN FIPE BREAK RESTRA NUMBER OF BARS 1AAD (Kipe)
DEFLECTION (inches)
RRSTRAINT DEFLECTION DEFLECTION (Inches)
IDENT.III IDENT. I PDA NCS PDA NSC PDA NSC PDA NSC PDA NSC RCl RCat 5
5 803.2 788.3 6.57 7.926 79.93 96.4 17.72 15.58 j
RC2 RCal 5
5 766.4 458.4 14.99 7.495 125 62.6 35.83 24.52 RC3 RCR2 6
6 747.0 639.7 2.27 3.73 27.65 45.35 17.16 20.11 g
RC3 RCR2 6
6 796.6 780.3 10.22 10.54 57.8 59.6 41.48 43.0 g
RC4 RHR) 5 5
846.0 838.4 7.64 8.05 92.95 97.98 18.87 16.43 gg RC4 RCR3 8
8 1319.0 1073.9 5.43 4.62 99.23 76.85 23.38 17.25 g
- RC4C, RCR3 8
8 1260.7 1275.0 4.49 5.58 80.37 99.89 22.56 18.73
- RC64, RCR3 8
8 928.5 722.5 1.22 I.77 22.46 31.7 23.68 95.39 l
- RC7, RCR7 6
6 953.3 801.6 6.28 5.76 76.4 70.12 16.46 21.63 RC8 '
RcR6 4
4 599.0 0
8.28 0
112.46 0
26.76 8.39 I'
W RCR7
'6 6
895.0 0
8.16 0
110.76 0
29.316 8.39
.m 1
- RC9C, RCR6 4
4 575.8 520.16 4.16 5.53 50.63 67.33 13.2 14.56 w
RC9 RCR8 6
6 830.2 546.8 11.408 6.815 95.29 56.9 36.612 26.24 gg RCil RCR8 6
6 818.3 493.6 10.98 5.99 91.72 50.07 31.404 23.71 g
RCl3 RCRio 4
4 668.4 478.0 5.87 3.66 93.5 58.39 13.37 10.44 RC16 BCall 4
4 687.4 518.4 6.59 4.38 105 69.86 15.37 10.22
- RCl4C, RCR20 8
8 285.0 309.6 2.83 5.88 46.3 95.92 15.45 13.96 RCl4 RCR20 8
8 116.3 129.9 0.96 3.36 10.5 37.1 22.13 23.56 g
MOTE:
1.
See Figure 3.6-49 s
n
%#5 4
vi
%r
O O
O TABLE 3.6-7 L
SUMMARY
OF MAIN STEAM PIPINC DESIGN ANALYSIS STRESSES AT BREAK LOCATIONSI2) 6 Main Steam "A" Piping:
a.
STRESS RATIOS (1)
USACE BREAK NODE EQ. (10)
EQ. (12)
EQ. (13)
FACTOR BREAK BREAK BASIS I.D. NO.(2)(4) yo, (3) 3Sm 3Sm 3Sm U
TYPE SECTION NO.(5) i SA1 001 0.45 0.22 0.27 0.00 cire.
Terminal End SA2A (SA1A) 002 1.14 0.83 0.36 0.02 Circ.
3.6.2.1.5.a.2.(c)
SA2LL (SAILL) 002 1.14 0.83 0.36 0.02 Long.
3.6.2.1.5.a.2.(c)
SA3C 029 0.53 0.10 0.29 0.05 Cire.
Terminal End 4
SA3A 021 0.72 0.36 0.38 0.00 circ.
Terminal End SA4LL-030 0.84 0.19 0.54 0.05 Long.
3.6.2.1.5.a.2.(b) i b.
Main Steam "C" Piping ("B" is a mirror image of Main Steam "C"):
i STRESS RATIOS (2)
USACE BREAK NODE EQ. (10)'
EQ. (12)
EQ. (13)
FACTOR BREAK BREAK BASIS I
I.D. NO.(2) yo, (3) 3Sm 3Sm 3Sm U
TYPE SECTION NO.
f SC1 001 0.42 0.19 0.27 0.00 Circ.
Terminal End SC2 (SCIA) 002 1.12 0.78 0.36 0.02 Circ.
3.6.2.1.5.a.2.(c)
SC4LL 030 0.87 0.20 0.56 0.06 Long.
3.6.2.1.5.a.2.(b)
SC3C 023 0.54 0.09 0.28 0.07 Circ.
3.6.2.1.5.a.2.(b)
SC5LL 046 0.86 0.20 0.56 0.06 Long.
3.6.2.1.5.a.2.(b)
Sc3A 020 0.71 0.34 0.38 0.00 Circ.
Terminal End s
?
i ci i
i I
I
O O
O TABLE 3.6-7 (Continued) c.
Main Steam "D" Piping STRESS RATIOS (l)
USACE BREAK NODE EQ. (10)
EQ. (12)
EQ. (13)
FACTOR BREAK BREAK BASIS I.D. NO.(2)(4)
NO. (3) 3Se 3Sm 3Se U
TYPE SECTION NO.(5) l SD1 001 0.45 0.22 0.28 0.00 Cire.
Terminal End SD2A (SDIA) 002 1.13 0.82 0.37 0.02 Cire.
3.6.2.1.5.a.2(c)
SD2LL (SD1LL)-
002 1.13 0.82 0.37 0.02 Long.
3.6.2.1.5.a.2(c)
SD3C 024 0.55 0.10 0.29 0.07 Circ.
3.6.2.1.5.a.2(b)
SD4LL 030 0.85 0.19 0.58 0.06 Long.
3.6.2.1.5.a.2(b)
SDSLL 046 0.82 0.15 0.58 0.06 Long.
3.6.2.1.5.a.2(b)
SD6LL 062 0.83 0.14 0.59 0.06 Long.
3.6.2.1.5.a.2(b)
SD7LL 090 0.83 0.17 0.58 0.05 Long.
3.6.2.1.5.a.2(b)
SD3A 021 0.71 0.35 0.39 0.00 Cire.
Terminal End i
Y T'
NOTES:
$l l
1.
These are the ratios of calculated stresses (by code equation) over allowable stresses.
I 2.
See Figure 3.6-65 for postulated break locations and break identification.
3.
See Figures 3.6-65a through 3.6-65f for noda locations.
4.
Perry unique break location designations in parentheses.
5.
Terminal end as defined in 3.,6.2.1.5.a.1.
a G
Y O
TABLE 3.6-8
SUMMARY
OF PIPE DESIGN ANALYSIS STRESSES IN PORTION OF MAIN STEAM LINES BETWEEN PRIMARY CONTAINMENT ISOLATION VALVES CUMULATIVE STRESS (psi)(2)
USACE 2.4Sm(3) 3.0Sm(3)
LINE NODE (1)
EQ(10)
EQ(12)
EQ(13)
FACTOR (psi)
(psi)
Main Steam 28 24,794 7,065 20,875 0.00 45,960 57,450 Line A Main Steam 28 24,534 6,856 20,848 0.00 45,960 57,450 Lines B and C Main Steam 29 25,470 7,443 20,857 0.00 45,960 57,450 Line D NOTES:
1.
See Figure (3.6-65a) for pipe node locations.
2.
Equation (10), (12), and (13) stresses and cumulative usage factors calculated in accordance with ASME Code,Section III, Subarticle NB-3650.
3.
Design stress intensity values, Sm, selected in accordance with Appendix 1 to ASME Code,Section III.
t 1
3.6-66 Am. 19 (5-13-85) t l
l
O O
O TABLE 3.6-9
SUMMARY
OF RECIRCULATION PIPING DESICN ANALYSIS STRESSES AT BREAK LOCATIONS (2)
STRESS RATIOS (l)
USAGE BREAK NODE EQ. (10)
EQ. (12)
EQ. (13)
FACTOR BREAK BREAK BASIS I.D. NO.(2)
NO. (3) 3Sm 3Sm 3Sm U
TYPE SECTION NO.(4) l RS1 100 0.51 0.16 0.44 0.00 Circ.
Terminal End RD1 202 0.50 0.14 0.48 0.00 Circ.
Terminal End RD2 183 0.67 0.26 0.48 0.00 circ.
Terminal End RD3 151 0.58 0.14 0.55 0.00 circ.
Terminal End RD4 184 0.61 0.20 0.46 0.00 cire.
Terminal End RDS.
203 0.62 0.21 0.48 0.00 cire.
Terminal End RD6LL 169 0.96 0.24 0.77 0.02 Long.
3.6.2.1.5.a.2.(c)
RD7LL 141 1.15 0.40 0.82 0.05 Long.
3.6.2.1.5.a.2.(c)
RD8LL 139 0.87 0.19 0.83 0.01 Long.
3.6.2.1.5.a.2.(c)
F RD9LL 166 0.85 0.17 0.79 0.01 Long.
3.6.2.1.5.a.2.(c) i RD6 169 0.96 0.24 0.77 0.02 Circ.
3.6.2.1.5.a.2.(c)
RD7 141 1.15 0.40 0.82 0.05 cire.
3.6.2.1.5.a.2.(c)
RD8 139 0.87 0.19 0.83 0.01 circ.
3.6.2.1.5.a.2.(c)
RD9 166 0.85 0.17 0.79 0.01 circ.
3.6.2.1.5.a.2.(c)
RHS1 64 0.80 0.23 0.67 0.01 Circ.
3.6.2.1.5.a.2.(c)
RilSILL 64 0.80 0.23 0.67 0.01 Long.
3.6.2.1.5.a.2.(c)
NOTES:
g 1.
These are the ratios for calculated stresses (by code equation) over allowable stresses.
l 2.
See Figure 3.6-66 and 3.6-66a for postulated break locations and break identification, g
3.
See Figure 3.6-66b for node locations.
4.
Terminal ends as defined in 3.6.2.1.5.a.1.
I m
Y t;
a5
O O
O TABLE 3.6-10 PEEDWATER PIPING SYSTEM OPERATINC STRESSES (l) AT BREAK LOCATIONS INSIDE CONTAINMENT Break I.D.
Node Eq 10 Eq 12 Eq 13 Useage Break Break Basis No.
No.
3 Sm 3 Sm 3 Sm Factor Type Section No. (2)
W1 435 0.767 0.436 0.453 0.03 Circ.
Terminal End W3 400 1.450 0.773 0.846 0.29 Circ.
3.6.2.1.5.a.2.c W3LL 125 1.303 0.607 0.851 0.20 Long.
3.6.2.1.5.a.2.c I
W4 335 0.695 0.364 0.534 0.03 Circ.
Terminal End l
W5A 333 1.261 0.800 0.477 0.12 cire.
3.6.2.1.5.a.2.c W5LL 333 1.261 0.800 9.477 0.12 Long.
3.6.2.1.5.a.2.c W6 300 1.522 0.834 0.851 0.42 cire.
3.6.2.1.5.a.2.c W6LL 110 1.702 0.942 0.893 0.58 Long.
3.6.2.1.5.a.2.c I
W7 275 0.804 0.440 0.471 0.03 Cire.
Terminal End s
W10 207 1.114 0.576 0.470 0.06 Cire.
3.6.2.1.5.a.2.c W10LL 95 1.437 0.559 0.936 0.25 Long.
3.6.2.1.5.a.2.c
.l i
NOTES:
1.
Ratio of calculated to allowable stress 2.
Terminal end as defined in 3.6.2.1.5.a.1 i
I
.I 5
I O
!h 4
=
l t
O O
O TABLE 3.6-11 EMERCENCY CORE COOLING SYSTEM OPERATING STRESSES AT BREAK LOCATIONS Break I.D.
Node EQ 10 (1)
EQ 12 (1)
EQ 13 (1)
Usage Break Break Basis No. (2)
No.
PSI PSI PSI Factor Type Section No. (3)
LPA 1 1
118285 14497 59171 0.46 Cire.
Terminal End LPA3B 8
103641 35358 26373 0.06 cire.
3.6.2.1.5.a.5.b Deleted LPB4B 25 110489 8380 58064 0.21 Cire.
3 6.2.1.5.a.2.c LPB4BLL 25 110489 8380 58064 0.21 Long.
3.6.2.1.5.a.2.c LPB4A 28 104168 6004 55771 0.15 Circ.
3.6.2.1.5.a.2.c LPB4ALL 28 104168 6004 55771 0.15 Long.
3.6.2.1.5.a.2.c LPB1 32 121234 11489 57640 0.63 Cire.
Terminal End LPCI 29 121100 6835 58164 0.48 Circ.
Terminal End
- p LPC4A 26 100721 3949 55446 0.12 cire.
3.6.2.1.5.a.2.c LPC4ALL 26 100721 3494 55446 0.12 Long.
3.6.2.1.5.a.2.c LPC4B 23 115229 5277 56683 0.23 Circ.
3.6.2.1.5.a.2.c LPC4BLL 23 115229 5277 56683 0.23 Long.
3.6.2.1.5.a.2.c LPA5 4
59905 6796
'26674 0.14 Circ.
3.6.2.1.5.a.2.c LPASLL 4
59905 6796 26674 0.14 Long.
3.6.2.1.5.a.2.c LPA6LL SW 82924 10583 27985 0.20 Long.
3.6.2.1.5.a.2.c hcl 27 90326 6956 41302 0.37 Cire.
Terminal End HC4 C 24 84930 5673 48155 0.19 Cire.
3.6.2.1.5.a.2.c g.
i HC4LL C 24 84930 5673 48155 0.19 Long.
3.6.2.1.5.a.2.c HCSA 24 80029 1889 54268 0.14 Circ.
3.6.2.1.5.a.2.c es T
HCSALL 24 80029 1889 54268 0.14 Long.
3.6.2.1.5.a.2.c h
HC5B 21 89729 5463 55213 0.16 Circ.
3.6.2.1.5.a.2.c i
5
O O
O i
TABLE 3.6-11 (Cont'd)
Break I.D.
Node EQ 10(1)
EQ 12 (1)
EQ 13 (1)
Usage Break Break Basis No. (2)
No.
PSI PSI PSI Factor Tyce Section No. (3)
HCSBLL 21 89729 5463 55213 0.16 Long.
3.6.2.1.5.a.2.c LC1 27 62851 11628 33041 0.07 Cire.
Terminal End LC2A 26 68654 28549 16470 0.10 cire.
3.6.2.1.5.a.2.c LC2LL 26 68070 28100 15858 0.09 Long.
3.6.2.1.5.a.2.c LC6 21 69439 2965 39245 0.05 circ.
3.6.2.1.5.a.5.b LC6LL 21 69439 2965 39245 0.05 Long.
3.6.2.1.5.a.5.b 1
NOTES:
1.
3 Sm = 53100 psi y
2.
See Figure 3.6-18 for postulated break locations and Lreak identification in LPCI.
[
See Figure 3.6-69a for postulated break location and break identification in LPCS.
8 See Figure 3.6-69b for postulated break location and break identification in HPCS.
3.
Terminal end is as defined in Section.3.6.2.1.5.a.1.
I
.I a
G
=
s, i
TABLE 3.6-12 FLUID BLOWDOWN THRUST TIME HISTORIES FOR MAIN STEAM PIPING SYSTEM Line A - Inside Containment (for NSSS Design and Analysis):
a.
BREAK TYPE OF SIDE OF F
Fint F
ti t2 o
ss LOCATION (1)(2). BREAK BREAK (kips)
(kips)
(kips)
(sec)
(sec)
SA1 Cire.
Turbine 446 312 208
.0037
.0988 SA2A (SA1A)
Cire.
Vessel 446 446 497
.00187
.01227 SA2A (SA1A)
Cire.
Turbine 446 312 208
.0037
.0988 SA2LL (SA1A)
Longit.
446 446 519
.00122
.00263 SA3C Cire.
Vessel 446 312 461
.01425
.05736 SA3C Cire.
Turbine 446 312 208
.00086
.03323 SA3A Cire.
Vessel 446 312 461
.01425
.05736 SA3A Cire.
Turbine 446 312 208
.00086
.03323 i
SA4LL Longit.
83 83 94
.00113
.00209 NOTE:
1.
See Figure 3.6-65 for postulated break locations and break identifications.
2.
Perry unique break location designations in parenthesis.
I I
l F,
55 I
I I
F "'
I I
I Fluid l Thrust l 1
l l
s g
t; t2 Time I
3.6-70 Am. 19 (5-13-85)
{
TABLE 3.6-12 (Continued) i b.
Lines B, C - Inside Containment (For NSSS Design and Analysis):
BREAK TYPE OF SIDE OF F
Fint F
El C2 o
ss LOCATION (1)(2) BREAK BREAK (kips)
(kips)
(kips)
(sec)
(sec)
SCI Cire.
Turbine 446 312 208
.0037
.0948 SC2 (SCIA)
Cire.
Vessel 446 446 506
.00187
.01227 SC2 (SCIA)
Cire.
Turbine 446 312 208
.0037
.0948 SC3A Cire.
Vessel 446 312 486
.01971
.06609 SC3A Cire.
Turbine 446 312 208
.00094
.01523 SC3C Cire.
Vessel 446 312 486
.01971
.06609 SC3C Cire.
Turbine 446 312 208
.00094
.01523 SC4LL Longit.
83 83 94
.00113
.00209 SCSLL Longit.
83 83 94
.00113
.00209 NOTE:
1.
See Figure 3.6-65 for postulated break locations and break identifications.
2.
Perry unique break location designations in parenthesis.
I I
~
l F,,
p, i
F "'
I I
I Fluid l 8
Thrust i I
I l
th Time t
l 3.6-70a Am. 19 (5-13-85)
(
t
TABLE 3.6-12 (Continued)
Line D - Inside Con :ainmer.t (for NSSS Design and Analysis):
c.
BREAK TYPE OF SIDE OF F
Fint F
El t2 o
ss LOCATION (1)(2) BREAK BREAK-(kips)
(kips)
(kips)
(sec)
(sec) l SD1 Cire.
Turbine 446 312 208
.0037
.0988 SD2A (SDIA)
Cire.
Vessel 446 446 497
.00187
.01227 SD2A (SDIA)
Cire.
Turbine 446 312 208
.0037
.0988 SD2LL (SD1LL), Longit.
446 446 519
.00122
.00263 SD3A Cire.
Vessel 446 312 461
.01425
.05736 SD3A Cire.
Turbine 446 312 208
.00086
.03323 SD3C Cire.
Vessel 446 312 461
.01425
.05736 SD3C Cire.
Turbine 446 312 208
.00086
.03323 SD4LL Longit.
83 83 94
.00113
.00209 SD5LL Longit.
83 83 94
.00113
.00209 SD6LL Longit.
83 83 94
.00113
.00209 SD7LL Longit.
83 83 94
.00113
.00209 NOTE:
1.
See Figure 3.6-65 for postulated break locations and break identifications.
2.
Perry unique break location designations in parenthesis.
I.
I I
l F,
ss i
F "'
1 I
I Fluid l Thrust i i
i I
O ti t2 Time 3.6-70b Am. 19 (5-13-85)
~
TABLE 3.6-12 (Continued)
O d.
26" Breaks - Inside Containment (for BOP Design Analysis):(1)
Flow Element Side of Break (2)
Time (seconds)
Thrust (Kips) 1 0.001 0-450.
.001.003 450.
.003.009 315.
.009-00 186.
Unrestricted Side of Break (2)
Time (seconds)
Thrust (Kips) 0.601 0-450.
.001.091(3) 305.
28" Breaks - Outside Containment (4) l e.
Break Time (sec)
Thrust (Kips)
SA-2, SA-3, SA-4, SA-5, SA-6, SA-7, SA-8, SA-9 Longitudinal Break (25.15" I.D.)
- 0..0118 0 - 509.
.0118
.24 509.
.25 - 00 439.
Double-Ended Break Reactor Side (25.15" I.D.)
- 0..001 0 - 509
.001
.31 509
.31 - 00 425 Turbine Side (25.15" I.D.)
- 0..001 0 - 509
.001
.31 509 4
.31 - 00 366 O
3.6-70c Am. 19 (5-13-85) i
_ _ _ _ _ _ _ _.. ~ _
J j
i NOTES:
1.
See Figure 3.6-65 for identification of postulated break locations.
_2.
I.D. of piping is 23.65".
Credit is taken for the main steam flow element (I.D. = 12.125") on one side of full circumferential breaks.
3.
Will decrease after tis time.
4.
See Figure 3.6-75 for identification of postulated break locations.
J
!O 4
i i
I 4
1 3
l l
O 3.6-70d Am. 19 (5-13-85)
TABLE 3.6-16 i
BLOWDOWN THRUSTS - HICH ENERGY PIPE BREAKS OUTSIDE CONTAINMENT i
I Initial Steady Blowdown State Line Break Thrust Thrust i
System Size Type 1bs lbs Remarks 4
{
Main Steam 28" Longit.
509,000 439,000 (2)
Main Steam 28" Circumf.
509,000 425,000 Reactor side (3)
Main Steam 28" Circumf.
509,000 366,000 Turbine side (3)
Feedwater 20" Circumf.
265,000 99,000 Pump side (4)
Feedwater 20" Longit.
265,000 99,400 (5)
Feedvater 36" Longit.
1,200,000 390,000 (6)
Feedwater 36" Circumf.
1,200,000 390,000 (8)
I Main Steam Drains 1-1/2" Circumf.
1,720 (7)
Main Steam Drains 2"
Circumf.
2,740 (7)
Main Steam Drains 3"
Circumf.
6,610 (7)
RWCU 4"
Circumf.
14,000 (7)
RWCU 4"
Longit.
14,000 (7)
RWCU 6"
Circumf.
32,250 (7) l RWCU 6"
Longit.
32,250 (7) 1 CRD Supply 2-1/2" Circumf.
13,000 100 Auxiliary Steam 1-1/2" Circumf.
340 (7)
Auxiliary Steam 3"
Circumf.
1,422 (7) j Auxiliary Steam 4"
Circumf.
2,450 (7)
Auxiliary Steam 4"
Longit.
2,450 (7)
Auxiliary Steam 10" Circumf.
15,181 (7)
Auxiliary Steam 10" Longit.
15,181 (7) i i
lO 3.6-74 Am. 19 (5-13-85) i m.... _ _ _.,,.
.__ - - _. -... _ - -. ~.
TABLE 3.6-16 (Cont'd)
O NOTES:
1.
(DELETED) 2.
Break number SA2LL, Figure 3.6-75 is typical 3.
Break number SA3, Figure 3.6-75 is typical
- i 4.
Break number WAl and WB1, Figure 3.6-76 is typical 5.
Break number WA2LL and WB2LL, Figure 3.6-76 is typical 6.
Break number W9LL, Figure 3.6-76 is typical 7.
Magnitude of the steady state blowdown thrust is a function of the location of the break relative to the pressure reservoir.
For design pressure, the initial thrust is assumed to govern jet effects analysis.
C.
Break number W9, Figure 3.6-76 is typical 7
4 4
i 1
J i.
3.6-75 Am. 19 (5-13-85) r
TABLE 3.6-17 V
PIPE WIP ANALYSIS EvPLOYINC STRAIN ENERCY METHOOS OR COMPONENT DAMACE STUDIES Impacting Impacted Systes Descriptien of Protectics Systes or Ceepenent or Qualificatien B-21 Restraints Energy-absorbing U-bolt or frame l Main Steam restraints inside containment -
see Section 3.6.2.3.3.1 B-33 Restraints Energy-absorbingU-boltorfrasel Recirculation restraints inside centainment -
see Sectic= 3.6.2.3.3.2 N-27 Restraints Energy-absorbirg U-bolt or frame Feedvater restraints inside and outside containment - see Section 3.6.2.3.3.3 E-12, 21, 22 Restraints Energy absorbing U-bolt or frase ECCS Lines restraints inside and cutside containment - see Section 3.6.2.3.3.4
()
E-51 Restraints Energy-absorbing U-bcit or frame RCIC Steam restraints inside and outside containment - see Section 3.6.2.3.3.5 Other High-Restraints Energy-absorbing U-bclt Energy Lines restraints inside containment -
see Section 3.6.2.3.3.4, 5, 6 M-29 M-23 HVAC Duct Low pressure stea= line Control Rs.
M-25 HVA2 Duct impacts safety-related
& Computer duct with. negligible Humidifier energy.
N-11 Non-Safety No impacted Safe-shutdown Main Steam in Stean Tunnel Cc=penents Turbine Building Steam Tunnel N-27 Non-Safety No impacted Safe-sautdcun Feedvater in Steam Tunnel Compenents Turbine Building Steam Tunnel (v3 3.6-76 Am. 19 (5-13-85)
TABLE 3.6-18
^
SUMMARY
OF SAFETY CLASS 1 HICH ENERCY PIPING SYSTEM OPERATING STRESS EXCEEDING BREAK POSTULATION CRITERIA Sub Break Stress Ratio (l)
Usage System Node I.D. No.
EQ. (10)
EQ. (12)
EQ. (13)
Factor N27 400 W3 1.813 0.966 1.058 0.29 125 W3LL 1.629 0.759 1.064 0.20 333 W5A 1.576 1.000 0.596 0.12 1
300 W6 1.903 1.043 1.064 0.42 110 W6LL 2.128 1.178 1.116 0.58 95 W10LL 1.796 0.699 1.170 0.25 67 0.814 0.050 0.769 0.39 i
10 0.738 0.010 1.016 0.05 1
20 0.743 0.016 1.053 0.05 B21 02 SA1A 1.43 1.04 0.45 0.02 02 SDIA 1.41 1.03 0.46 0.02 l
l B33-141 RD7LL 1.44 0.50 1.02 0.05 l
139 RD8LL 1.09 0.24 1.04 0.01 l
141 RD7 1.44 0.50 1.02 0.05 139 RD8 1.09 0.24 1.04 0.01 iO 1E12G09 01 LPA1 2.784 0.341 1.393 0.46 04 LPA5 1.410 0.160 0.628 0.14 SW LPA6LL 1.952 0.249 0.659 0.20 1E12C10 25 LP848 2.601 0.197 1.367 0.21 i
i 28 LPB4A 2.452 0.141 1.313 0.15 t
}
32 LPB1 2.854 0.270 1.357 0.63 i
1E12C11 29 LPC1 2.851 0.161 1.369 0.48 26 LPC4A 2.371 0.093 1.305 0.12 23 LPC4B 2.713 0.124 1.334 0.23 1E22C04 27 hcl 2.126 0.164 0.966 0.37 C24 HC4 1.999 0.134 1.134 0.19 24 HCSA 1.884 0.044 1.277 0.14 21 HC5B 2.112 0.129 1.300 0.16 IC41C05 7
SLS 2.240 0.314 1.098 0.32 9
SL7 1.878 0.161 1.114 0.11 10 SL14 1.786 0.101 1.134 0.07 8
SL6 1.879 0.216 1.031 0.11 27 SL13 1.917 0.160 0.980 0.11
- O 4
l 3.6-77 Am. 19 (5-13-85)
I
l l
1 TABLE 3.6-18 (Continued)
Sub Break Stress Ratio (1)
Usage System Node I.D. No.
EQ. (10)
EQ. (12)
EQ. (13)
Factor 1E51007 46
.HS1 1.958 0.106 0.921 0.27 1
HS2 2.185 0.091 1.262 0.79 4
HS3 2.176 0.055 1.263 0.75 99 HVL7 1.648
.0.056 0.860 0.19 101 HVL8 1.342 0.053 0.942 0.18 81 HVL3 0.987 0.00 0.00 0.26 82 HVL16 0.843 0.00 0.00 0.10 1C33C01 13 RW2 1.052 0.310 0.451 0.14 16 RW3 1.029 0.290 0.438 0.13 27 RW237 1.311 0.485 0.483 0.23 28 RW238 1.270 0.448 0.473 0.22 30 RW239T 1.111 0.344 0.434 0.16 31 RW240T 1.058 0.311 0.418 0.15 52 RW9 2.594 1.124 0.681 0.80 54 RW10 1.779 0.696 0.471 0.75 55 KW129 1.002 0.174 0.439 0.13 56 RW130 1.441 0.468 0.462 0.27 57 RW131 1.292 0.385 0.464 0.21 59 RW132 1.030 0.247 0.450 0.15 n/
60 RW133 1.310 0.155 0.467 0.13 A.
72 RW134 1.173 0.096 0.485 0.30 i
211 RW135 1.320 0.048 0.731 0.11 J
78 0.808 0.000 0.000' O.13 FW1 0.720 0.17 192 RW43 2.222 0.432 0.843 0.10 503 RW232 1.351 0.597 0.549 0.31 i
504 RW233 1.314 0.559 0.539 0.27 21 RW234 1.208 0.403 0.529 0.19 22 RW235 1.268 0.409 0.476' O.19 24 RW236 1.333 0.427 0.486 0.21 505 RW241 1.341 0.122 0.455 0.10 506 RW242 1.340 0.148 0.444 0.10 39 RW229 1.299 0.387 0.543 0.19 77 RW136 1.037 0.214 0.692 0.14 189 RW39 2.227 0.192 0.982 0.14 74 RW17LL 2.204 0.372 1.100 0.28 20 0.990 0.000 0.000 0.10 501 RW230 1.116 0.336 0.505 0.15 502 RW231 1.160 0.373 0.511 0.17 NOTE:
1.
Stress ratio is the calculated stress divided by 2.4 Sm O
3.6-78 Am. 19 (5-13-85)
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Penetration Guard Pipe Type APERTURE "x" sain steam CARD Figure 3.6-55 (GAI Dwg. B-312-641)
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- G
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NUCLEAR Ii$5$0ftLO. SAFETY RELATED Mso Avadable On rTAChMENTS AND COMPONENTS W ARnEJ THUS $ ARE IN%GRAL PAG ~i 0F THE CONTAlhuEhi ^PCffDre Card AFION ASSEZtY, CL ASS REFERS TO PROCESS PIPc CNLY. 'P"CES3 81PE SUPPCRTS TO BE th ACCORDANCE film t TER INTECRAL PARTS TO BE IN ACCORNNCE flTh tC OF THE ASME SECil0N lit C00E. ] LTERI AL AND SPECIFICATI0hi, SEE I,Al SPECIFIC ATION t8-527-4549-00 AND SP-525-4549-00. MERTURE
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Am. 19 (5-13-85) PERRY HUCLEAR POWER PLANT pfp ' THE CLEVELAND ELECTRIC 'w ILLUMINATING COMPANY f Penetration Guard Pipe Type "Q" Feedwater Figure 3.6-58 (GAI Dwg. B-312-650)
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0 90 R3558 RD6 / LL R3568 R3548 so w I I 0 270 0 R3518 R3528 R3538 LL R3038 RD7 R3578 / [ R3588 D8 R3598 LL O "tN ACTIVE" R3028 (LOOP '8' ON M V f "lN ACTIVE" R3018 (LOOP '8' ONLY) l THIS IS REPRESENTATIVE OF LOOP'B' LOOP'A'SAME AS LOOP'8*(EXCEPT FOR RHR SUCTION) SREAKS ARE POSTULATED ONLY Am. 19 (5-13-85) AT NUM8ERED LOCATIONS SHOWN PERRY NUCLEAR POWER PLANT INNp THE CLEVELAND ELECTRIC ILLUMINATING COMPANY Recirculation System Piping Postulated Break Locations and Restraint Locations Figure 3.6-66
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t O Also Awdlable On Aperture Card TI APEllTURE CARD Am. 19 (5-13-85) /-, PERRY NUCLEAR POWER PLANT / pNo THE CLEVELAND ELECTRIC ILLUMINATING COMPANY $er$nskdebo$!ai$ ment Fee RS97A @ Sgg4 ./ Figure 3.6-67 9606/7&f14%
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~~ O* ) / / Also AWIe On 3 Aperture Card 'g/ .S ..(LPA3B TI lZ-Fo3c)A APERTURE 4, CARD RP203A s E11-F04t A ( h k' Am. 19 (5-13-85) ~' PERRY HUCLE AR POWER PLANT /g ,AND THE CLEVELAND ELECTRIC ILLUMINATING COMPANY y., 6 Pipe Rupture Locations A LPCI (RllR) I nsid'e' Con t a inmen t Figure 3.6-68 ~~ s rA %CpfyO +Y'f-M
RPV Y._ 27o* \\. i / G n60* s c. ,/ E7_1 -F O( R7C L7C LPCS-NOTES: I-BREAK 5 ARE. POSTULATED ONLY AT NUMBERF_D LOCAT\\DMS SH OWN. l l
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3 90* 18 0* >/ \\ .N. ( s 0l O 'N 27O' u c(a iLig RPV RCIC-4 0* RESTRANT STROOTORF-Also Andable On Aperinre Card TI Q Dt.zotA APERTURE CARD h SH3 xn PIPE GUIDE 42o1 u. 19 (5-13-85) (,MK-\\ 42 - ESt H\\o2) PERRY NUCLEAR POWER PLANT LLUM NATING COMPANY Pipe Rupture Locations RCIC Steam-Inside Cnotainment Figure 3.6-70
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m-l' HS2 C gct 6 g \\6 po6 pg .3 / f W-6 s RHVD-3 Notg EAn.4 NOT E '. I-PIPE RUPTURE.5 ARE POSTULATED ONLY AT F17T/NG WELDG SHOWN.
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TI APERTURE "ac vma 9 CARD "4' 4 aTts l i CRD-I6.,l 1 / l s s v u s CONT. CH ONG. Am. 19 (5-13-85) pl30 p,G;p jr PERRY NUCLEAR POWER PLANT PN THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FitL CRD Supply - Inside Containment Figure 3.6-72 (Sheet 1 of 3) t
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g,A g:c'l ~ 0 / y / / ./ / / / ~~ 't%Ie o, 2~ sPedare Card V t' J ,p* ' TI APERTURE CARD Sets c8ARGI yg w N cc00 MQTES*. i( l-BREAWS ARE POSTULATED AT g ? ACH MELO AMD F\\TTIMC. SHOWh. l 2-THRUST \\S FR0ti 5b?PL't 5\\DE l ?, 1 OMLY. CRD -l4 l Am. 19 (5-13-85) PERRY HUCLEAR POWER PLANT DNA THE CLEVELAND ELECTRIC N ILLUMINATING COMPANY CRD Supply - Inside Containment Figure 3.6-72 (Sheet 2 of 3) >-s J
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THE CLEVELAND ELECTRIC M ILLUMINATING COMPANY CRD Supply - Inside Containment 'Ffgure 3.6-72 (Sheet 3 of 3) r
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- 1. N O BREAKS ARE POSTO LATE.O. ALL PlPE SHOWN IS IN BREAK EXCLUSION AREA.
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'3 Cy P V N4/g Gim O O(O'4 / q g k4 / Ab / Also Ay,gjable On A erture Card P TI y APERTURE can 3 ( Am. 19 (5-13-85) G PERRY NUCLEtt POWER PLANT THE CLEVELAND ELECTRIC ILLUMINATING COMPANY Pipe Rupture Locations MS Outside Containment Figt.re 3.6-75 95~d G/70#F1-W
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PERRY NUCLEAR POWER PL ANT AN THE CLEVELAND ELECTRIC ILLUMINATING COMPANY Pipe Rupture Locations RWCU/RI?R To FW Outside Containment \\t'gure 3.6-78 'Fi e 97opsi47
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JET BOUNDARY )RYWELL WALL B8EAK SD3A g-r. l,, ./, \\ t BREAK SD3A f / \\ / i ! '/ / l l / / ( 1 HPCS i _. 1. - 4 ( ( _) _) _. _ 1 t CL.G3/ / l ~ BREAK SBSA \\\\ .x \\ \\ 5 '\\~ I,__ s / s. i ~ ..-x. / BREAK SB3A SECTION H Also Available On Aperture Card l TI APERTURE a, 1,(3_13_s3) PERRY NUCLE AR POWER PLANT (pnp THE CLEVELAND ELECTRIC j %/ ILLUMINATING COMPANY Jet Impingement MS Jet Striking HPCS Figure 3.6-31 l VRe76'A?Y ~5b
O Figures 3.6-82 and 3.6-83 (Deleted) \\ l Am. 19 (5-13-85)
~ PL AM VIEW I B\\ 0- WALL o I --A 'b~\\ \\ 1 m \\ ,e \\ / \\ 1 i rm i om Qf> .) J v 1 / t D i ..._ J. EL6?S-1O' JET SHIELD RBR BREAt I O I REC \\RCULATION i I O DISCHRRGE MERDER ij A R P V. A1. 24 0 l 1
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Figure 3.6-84 S\\DE VIEW _ El', frs ] 6/ 7 d f
1 O Figures 3.6-86, 3.6-87, 3.6-88, and 3.6-89 (Deleted) O i 1 O Am. 19 (5-13-85) l l 1 --w, - ~. - - -, - - ~ - - ~ - - - -, - ~ - r -~v- -- "~ ' ' ' " "'
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MOTES *. qg 1-it1P\\MGE.nEMT OM \\0G BUNDLE FROM RDAE AT \\?_0'\\S OPPOS\\TE HAMD. 7_-\\MP\\MGV_MEMT OM 254 BUMDLE FROM RDBl AT 24(f \\5 51M\\LAR TO TH AT SHOWN FOR ROA 1 3-\\MPIMGEMEMT OM ?R BURDLE FRBM RDBS AT 300 is 5\\M\\LAR TO RDAS. A Yella bie u n A erture Card P TI APERTURE CARD Am. 19 (5-13-85) PERRY NUCLEAR POWER PLANT 'N THE CLEVELAND ELECTRIC ILLUMINATING COMPANY Jet Impingement Recirc. Jet Striking.CRD Lines J Figure 3.6-85 953978W7 =%
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I t O l Figures 3.6-93 and 3.6-94 l (Deleted) O f l I l O Am. 19 (5-13-85) .}}