ML092510256
| ML092510256 | |
| Person / Time | |
|---|---|
| Site: | Vogtle  |
| Issue date: | 04/30/2009 |
| From: | Westinghouse |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| WCAP-17071-NP, Rev 0 | |
| Download: ML092510256 (25) | |
Text
Attachment Attachment 33 Corrected Corrected Pages Pages for for WCAP-17071-NP WCAP-17071-NP (Non-Proprietary)
(Non-Proprietary)
1-5 1-5 Prior calculations calculations assumed that contact pressure pressure from the tube would expand the tubesheet bore uniformly uniformly without considering considering the restoring forces from adjacent pressurized pressurized tubesheet tubesheet bores. In the structural model, a tubesheet tubesheet radius dependent stiffness effect effect is applied applied by modifying the representative representative collar thickness thickness (see Section Section 6.2.4) of the tubesheet material surrounding surrounding a tube based on the position position of the tube in the bundle. The basis for the radius dependent dependent tubesheet tubesheet stiffness effect is similarsimilar to the previously previously mentioned mentioned "beta "beta factor" approach. The "beta factor" was a coefficient coefficient applied to reduce the crevice crevice pressure pressure to reflect the expected expected crevice pressure pressure during normal operating operating conditions conditions in some prior H*
calculations calculations and is no longer used in the structuralstructural analysis of the tube-to-tubesheet joint. The current structural structural analysis consistently includes includes a radius dependent dependent stiffness calculation described in detail in Section 6.2.4. The application of the radius dependent stiffness factor has only a small effect on the ultimate ultimate value of H* but rationalizes rationalizes the sensitivity sensitivity of H* to uncertainties uncertainties throughout throughout the tubesheet.
The contact pressure pressure analysis methodology methodology has not changed changed since 2007 (Reference (Reference 1-9). However, However, the inputs to the contact pressure pressure analysis and how H* is calculated have changed in that period of time. The details details describing the inputs to the contact pressure pressure analysis are discussed in Section 6.0.
The calculation calculation for H* includes the summation of axial pull out resistance resistance due to local interactions interactions between between the tube bore and the tube. Although tube bending bending is a direct effect effect of tubesheet displacement, displacement, the calculation calculation for H* conservatively conservatively ignores any additional pull out resistance resistance due to tube bending within within the tubesheet or Poisson expansion effects effects acting on the severed tube end. In previous submittals, the force resisting pull out acting on a length of a tube between between any two elevations hi and h2 was defined in Equation (1-1):
(1-1):
F= (h 2 -h,)FHE + ddfhrP dh
.,nI (1-1)
(1-1) where:
FHE F HE = Resistance per length to pull out due to the installation installation hydraulic hydraulic expansion, d = Expanded tube outer diameter, P
P = Contact pressure pressure acting over the incremental incremental length segment dh, and,
ýt f.l = Coefficient of friction between between the tube and tubesheet, conservatively conservatively assumed assumed to be 0.2 for the pull out analysis analysis to determine H*.
The current H* analysis generally generally uses the following equation to determine determine the axial pull out resistance of of a tube between any two elevations h2:
elevations hi and h2:
a,c,e
[K ]1 (1-2)
(1-2)
Where the other parameters (1-2) are the same as in Equation (1-1) parameters in Equation (1-2) (1-1) and [
]a,c,c
]ac"c AA detailed detailed explanation of the WCAP- 17071-NP WCAP-17071-NP April 2009 2009 Revision 0
1-6 1-6 revised revised axial pull out equation are included in Section 6.0 of this report. However, However, the reference reference basis for the H* analysis is the assumption that residual contact pressure contributes resistance to contributes zero additional resistance to tube pull out. Therefore, Therefore, the equation equation to calculate calculate the pull out resistance in the H* analysis is:
h, h,
F, == ,u F; 7d JPdh Jurd Pdh
",/71 (1-3)
(1-3) 1.3.2 Leakage Integrity Analysis Leakage Prior submittals of the technical technical justification justification of H* (Reference 1-9) argued that K was a function of the (Reference 1-9)
Pc, and, therefore, that resistance was a function of the location within the'tubesheet.
contact pressure, P,, the' tubesheet.
The total resistance resistance was found as the average value of the quantity ,uK, j.LK, the resistance per unit length, multiplied by L, or by integrating integrating the incremental resistance, dR ==/.K incremental resistance, j.LK dL over the length L, i.e.,
R= = ;1K K (L L I ) = f1 (L22 --LI)=,4 l'
["
KdL K dL (1-4)
(1-4)
Interpretation of the results from multiple leak rate testing programs Interpretation programs suggested suggested that the logarithm logarithm of the coefficient was a linear loss coefficient linear function of the contact pressure, pressure, i.e.,
InK = a0 + alPc (1-5)
(1-5) where the coefficients, coefficients, ao and a,a1 of the linear relation were based on a regression analysis of the test data; both coefficients coefficients are greater greater than zero. Simply put, the loss coefficient was determined determined to be greater greater than zero at the point where the contact pressure is zero and it was determined determined that the loss coefficient coefficient increases with increasing increasing contact pressure. Thus, K = ea-+aP, (1-6)
(1-6) and the loss coefficient exponential function of the contact pressure.
coefficient was an exponential The B* distance (LB) was defined as the depth at which the resistance to leak during SLB was the same as that during normal operating conditions conditions (NOP) (using Equation 1-4, the B* distance was calculated calculated setting RSLB = RRNop Nop and solving for LB). Therefore, Therefore, when calculating calculating the ratio of the leak rate during the design basis accident condition to the leak rate during normal operating operating conditions, conditions, the change in in magnitude of leakage leakage was solely a function of the ratio of the pressure pressure differential differential between the design basis accident and normal operating plant conditions.
The NRC Staff raised several concerns concerns relative relative to the credibility credibility of the existence of the loss coefficient coefficient versus contact pressure pressure relationship relationship used in support of the development of the B* criterion:
WCAP- 17071-NP WCAP-1707l-NP April 2009 Revision Revision 00
1-13 1-13 Conservatisms in the H* Structural and Leakage Table 1-1 List of Conservatisms Leakage Analysis Analysis (Continued)
Assumption/Approach Assumption!Approach Why Conservative?
Conservative?
A((
A This is conservative conservative because stiffness of the solid and perforated because it reduces the stiffness perforated regions of the tubesheet to the lowest level for each operating condition condition (see (see Section Section 6.2.2.2.2).
a,c,e
]a,c,e Pressure is not applied to the Applying pressure to the [
Applying
[
a,c,e (see (see Section Section 6.2.2.2.4).
]a,c,e The The radius dependent stiffness Including these structures in the analysis analysis would reduce the tubetubesheet displacement and limit the local deformation sheet displacement deformation of the analysis presence of analysis ignores the presence tubesheet hole ID (see tubesheet (see Section 6.2.4.4).
the [
a,c,e
]a,c,e The tubesheet bore dilation [ Thermal expansions under operating operating loads were [
]",c,e (see Section 6.2.5).
(see Section Ja,c,e (e eto .. )
a,c,]..
conditions).
2250 (NOP conditions).
WCAP- 17071-NP WCAP-17071-NP April 2009 Revision 0
5-3 5-3 5.3 5.3 CALCULATION OF APPLIED CALCULATION APPLIED END CAP LOADS LOADS The tube pull out loadsloads'l (also called end cap loads) to be resisted during normal normal operating operating (NOP) and and faulted conditions for the bounding Model F plant (Millstone Unit 3) for the hot leg are shown below.
End cap load is calculated calculated by multiplying the required factor of safety safety times the cross-sectional cross-sectional area of the tubesheet bore tubesheet bore hole times the primary side to secondary secondary side pressure difference difference across the tube for each each plant condition.
End Cap H* Design H*Designcap IAOperating Condition ( kp (Ppri-dP (psi) (Ppri- Area (in)2)
Area (in EnLoadCap Factor of Factor of Operating Condition Load End Cap P sce ) (Note 1)
(Note (lbs.) Safety Load (Lbs.) a,c,e (lbs.) Load (Lbs.) a,c,e r-Normal Op. (maximum)
)
Faulted (FLB)
Faulted (SLB)
(SLB)
Faulted Faulted (Locked Rotor)
Faulted (Control Rod Ejection)
Notes:
- 1. Tubesheet Cross-Sectional Area Area ==1 ]a,c,c t,e,e The above calculation of end cap loads is consistent consistent with the calculations calculations of end cap loads in prior H*
justifications and in accordance accordance with the applicable industry applicable industry guidelines (Reference 5-3). This approach (Reference approach results results in conservatively conservatively high end cap loads to be resisted during NOP and faulted conditions because because a cross-sectional cross-sectional area larger than that defined by the tube tubesheet sheet bore mean diameter is assumed.
The faulted condition end cap loads will not vary from plant to plant among among the Model Model F population population for the postulated FLB for 3- 3- and 4-loop 4-1oop plants because because the specified transient transient for both is the same. The value for end cap load for a 3-loop 3-100p plant is different different than the value for a 4-loop 4-100p plant for a postulated SLB event event and is also provided provided above.
above. The values vary only slightly for the locked rotor event and control rod ejection ejection event event from plant to plant (see Table Table 5-6).
The end cap loads noted above include a safety factor of 33 applied to the normal operating end cap load and a safety factor of 1.4 applied applied to the faulted condition end cap loads to meet the associated structural performance performance criteria criteria consistent with NEI 97-06, Rev. 2 (Reference 5-3). 5-3).
Seismic loads have also been considered, but they are not significant in the tube joint region of the tubes (Reference (Reference 5-1).
5-1).
H* values are not calculated for the locked rotor and control rod ejection transients because the pressure differential differential across the tubesheet is bounded bounded by the FLB/SLB transient. For plants that have a locked rotor I The values for end cap loads in this subsection of the report are calculated calculated using an outside diameter of the tube equal to the mean diameter of the tubesheet bore plus 2 standard standard deviations.
WCAP-17071-NP WCAP-17071-NP April 2009 Revision Revision 0
5-4 5-4 open PORV transient included with stuck open bounded by the included as part of the licensing basis, this event is bounded transient is significantly less than that of the FLB/SLB event because the peak pressure during this transient SLB/FLB transient.
WCAP- 17071-NP WCAP-17071-NP April 2009 Revision 00 Revision
5-5 5-5 Table 5-7 Operating Conditions - Model F H* Plant Plant Plant Plant Parameter and Units Salem Unit 1(1) Millstone Unit 3(2) [ Unit 1(3)
Seabrook UnitsVogtle 1 and 2(4) Wolf Creek (5)
WolfCreek (5) Vandellos n(6)
Vandellos 11(6)
Unit 1(I) Unit 3(2) Unit 1(3) Units 1 and i4)
Power NSSS -
Power - MWt 3471 3666 3678 3653 3579 NSSS MWt 3471 3666 3678 3653 3579 2954 NSSS Primary Pressre Primary psia 2250 2250 2250 Pressure pSla 2250 2250 2250 2250 2250 Pressure Psia Psia (Low (Low r- - a,C,C a,c,c Secondary Secondary Tay/High Tavg/High Pressure Pressure Tayg)
Tavg)
Reactor Reactor 'F (Low of Vessel Vesse! Outlet Tavg/High Tay/High Temperature Temperature Tayg)
Tavg)
SG Primary-Primary-to-Secondary to-Secondary Psid (Low Pressure Tavg/High Tay/High Differential Differential Tayg)
Tavg) '-- -
(psid)
(psi41 I I I
()(I) PCWG-2635, PCWG-2635, Revision 1, Salem UnitsUnits 1 and 2 (PSE/PNJ):
(PSE/PNJ): Approval of Category Category IV (for Implementation)
Implementation) and IVP (for Limited Limited Implementation)
Implementation) PCWG Parameters Parameters to Support 1.4% Uprate, 2/8/05.
Support 1.4%
(2)
(2) PCWG-06-9, Millstone Unit 3 (NEU): Approval of Category II (for Contract) PCWG Parameters to Support a 7% Stretch Power Uprate PCWG-06-9, Millstone Unit 3 (NEU): Approval of Category II (for Contract) PCWG Parameters to Support a 7% Stretch Power (SPU) Program, 4/25/06.
(3)
(3) PCWG-08-68, Seabrook Unit 1 (NAH): Approval of Category IV PCWG Parameters to Support a 7.4%
PCWG-08-68, Seabrook Unit 1 (NAH): Approval of Category IV PCWG Parameters to Support a 7.4% Uprate Program, 11/7/08. 11/7/08.
(4)
(4) PCWG-05-49, Vogtle Units 1 and 2 (GAE/GBE): Approval of Category III (for Contract) PCWG Parameters to Support 2%
PCWG-05-49, Vogtle Units 1 and 2 (GAE/GBE): Approval of Category III (for Contract) PCWG Parameters a 2%
Measurement Measurement Uncertainty Uncertainty Recapture Recapture (MUR) Uprate, 11/ 18/05.
Uprate, 11118/05.
(5)
(5) PCWG-2417, Wolf Creek Unit 1 (SAP): Approval of Category IVP Parameters to Support a Best Estimate Flow for PCWG-2417, WolfCreek Unit 1 (SAP): Approval of Category IVP Parameters to Support a Best Estimate Flow Reactor Coolant Coolant Pump (RCP)
(RCP) Replacement, 6/17/99.
611 7/99.
(6)
(6) PCWG-06-15, Revision 1, Vandellos Unit II (EAS): Approval of Category IVP PCWG Parameters to Support a Tavg Range Program, PCWG-06-15, Revision 1, Vandellos Unit II (EAS): Approval of Category IVP PCWG Parameters to Support a Tayg 6/15/06.
6/15/06.
WCAP-17071-NP WCAP-17071-NP April April 2009 Revision 0 Revision
5-6 .
5-6 Table Table 5-8 Steam Line Line Break Break Conditions Millstone Seabrook Vogtle Units Vandellos Parameters and Parameters and Units Units Salem Unit 1 WolfCreek n(l)
Unit 3 Unit 1 land 2 a,c,e a,c,e
]
Peak Peak Primary-Secondary Primary-Secondary Pressure Pressure (psig)
(psig) 1 Primary Primary Fluid Fluid Temperature Temperature (°F)
(OF) (HL (HL and and CL)
Secondary Secondary Fluid Fluid Temperature Temperature (OF)('F) (HL (HL and and CL)
CL)
II (1) () Three-loop Three-loop plant, plant, all all other other Model Model FF H*
H* plants plants are are 4-loop 4-loop plants.
plants.
HlL HL-Hot- Hot Leg Leg CL CL- - Cold Cold Leg Leg WCAP-17071-NP WCAP-l707l-NP April April 2009 2009 Revision Revision 00
5-7 5-7 3
Feedwater Line Break Conditions 3 Table 5-9 Feedwater Parameters Millstone Unit Seabrook V ogtle Units Parameters and Units Salem Unit 1 Millstone 3 Unit Seabrook Unit I Vogtle I andUnits 2 Wolf Creek WolfCreek Vandellos Vandellos II II 3 Unit 1 1 and 2 Pressure (psig)
Primary-Secondary Pressure Peak Primary-Secondary F- - ac, a,c,c Primary Primary Fluid Temperature (°F)(I)l ) (HLlCL)
Temperature (OFi (HL/CL)
Secondary Secondary Fluid Temperature Temperature (OF)(')
(oF)(I) (HL and CL)
Primary Primary Fluid Temperature Temperature (OFP) (HL/CL)
('F)(2) (HLlCL)
Secondary Fluid Temperature (OFP)
Secondary (°F)( 2 ) (HL and CL) I- -
(I)
(1) Low Tavg Low Tavg (2)
(2) High Ta,,vg High Tavg (3)
(3) The The pressures pressures and and temperatures included in temperatures included in this table for this table for aa postulated postulated FLB FLB are used for are used for the the structural structural analysis and are based based on the SG design design specification specification transient. The pressure pressure and temperatures temperatures used for the leakage analysis for FLB are identified identified in Section Section 9.0 of this report.
HL - Hot Leg HL-Hot CL - Cold Leg WCAP- 17071 -NP WCAP-17071-NP April 2009 Revision 00 Revision
5-8 Table 5-10 Locked Locked Rotor Event Conditions Millstone Seabrook Vogtle Units 1 Vandellos II Vandellos II
~ ntsU Parameters andPar m et rs a d Units Salem Salem Unit 1I nit 3 Millstone Seabrook U nit I1 andUnits Vogtle and 22 1 Wolf Creek WolfCreek a,c,e ace Unit 3 Unit
~
Peak Primary-Secondary Primary-Second1\!Y Pressure (psig)
Primary Temperature (OFP)
Primary Fluid Temperature (OF)(1) (HLlCL)
(HL/CL)
Secondary Fluid Temperature Temperature (OF)(I)
(°F)(' (HL and CL)
CL)_
Primary Primary Fluid Temperature (°F)( 2) (HLlCL)
Temperature (OFP) (HL/CL)
Temperature (OF)(2)
Secondary Fluid Temperature (°F)(2) (HL and CL)
~
CL)_ , -
(1)
(I) Low Tavg Low Tavg (2)
(2) HighTavg HighTavg HL - Hot Leg HL-Hot CL - Cold Leg CL-Cold WCAP-17071-NP WCAP-1707l-NP April 2009 Revision 0
5-9 5-9 Table 5-11 Control Rod Ejection Ejection Parameters and Parameters and Units Units Salem Unit 11 Salem Unit Millstone Millstone Unit Unit 3 Seabrook Seabrook Unit Unit 1 rVogtle Units Vogtle andUnits l1 and 22 WolfCreek Wolf Cre ek Vandellos II Vandellos II a,c,e a,c,e r--
Peak Peak Primary-Secondary Primary-Secondary Pressure Pressure (psig)
(psig)
Primary Primary Fluid Fluid Temperature (OFi l ) (HL/CL)
Temperature (°F)(1) (HLlCL)
Secondary Secondary Fluid Fluid Temperature (OFi l ) (HL Temperature (°F)(1) (HL and and CL)
CL)
Primary 2 Primary Fluid Fluid Temperature Temperature (°F)(
(OFi 2)) (HL/CL)
(HLlCL)
Secondary Secondary Fluid Fluid Temperature (OFP) (HL Temperature (°F)(2) (HL and and CL)
CL) '-
(I)
(1) Low Low Tavg Tavg (2)
(2) High Tavg High Tavg HL - Hot Leg HL-HotLeg CL - Cold Leg CL-ColdLeg WCAP-17071-NP WCAP-17071-NP April April 2009 2009 Revision Revision 00
5-10 5-10 Table 5-12 Design End Cap Loads for Normal Operating Plant Conditions, Locked Rotor and Control Rod Ejection for Model F Plants Plants Low Tavg Tavg High Tavg High Tavg Control Rod Ejection Ejection Plant End Cap Load End Cap Load Locked End Cap Load Plant w/Safety Factor w/Safety Factor End CapRotor Load (lbf) w(Safety Factor w(Safety Factor End Cap Load (lbf)
(lbf) (lbf)
(lbf) (lbf) r- -
Salem Unit I1 a,c,e a,c,e Millstone Unit 2 Seabrook Seabrook Vogtle Units 1 and 2 Wolf Creek WolfCreek Vandellos II L...-
WCAP-17071-NP WCAP-17071-NP April April 2009 2009 Revision 0
6-10 6-10 Therefore, Therefore, hnomina!
hnominal =
= ([ )",e,e inch (i.e.,
]... (i.e., [( ]a.c.. and Tj
)",e,c 11 =
= ([ ]a,e,e when the tubes are not
]a,,,,
included. From From Slot (Reference 6-5) the in-plane in-plane mechanical mechanical properties for Poisson's ratio of 0.3 are:
Property Property Value a,c,e a,c,e E*p /E/E P -
V E 1/E E*1 / E =
d Vd =
E* / E E*/E =
v V L Elastic Elastic modulus of solid solid E - material material where the subscripts p and d refer to the pitch pitch and diagonal directions, directions, respectively. These values values are substituted into the expressions expressions for the anisotropic elasticity elasticity coefficients coefficients given previously. The coordinate system used in the analysis and derivation of the tubesheet equations is given in Reference Reference 6-4.
Using the equivalent equivalent property property ratios calculated above in the equations presented at the beginning equations presented beginning of this section yields the elasticity coefficients for the equivalent solid plate in the perforated perforated region region of the tubesheet for the finite element element model.
three-dimensional structural model is used in two different analyses:
The three-dimensional analyses: 1)I) a static structural analysis analysis with applied pressure loads at a uniform temperature temperature and 2) a steady-state steady-state thermal thermal analysis with appliedapplied surface loads. The solid model and mesh is the same in the structural structural and thermal analyses analyses but the element types are changed to accommodate accommodate the required required degrees of freedom (e.g., (e.g., displacement displacement for structural, temperature for thermal) for each analysis. The tubesheet displacements for the perforated structural, temperature perforated region of the tubesheet tubesheet in each analysis are recorded for further use in post-processing. Figure 6-2 and Figure 6-3 are screen shots of the three-dimensional three-dimensional solid model of the Model Model F SG. Figure 6-4 shows the entire 3D model mesh.
WCAP-17071-NP WCAP-17071-NP April 2009 2009 Revision 0
6-18 6-18 a,c,e a,c,e K
with the elasticity coefficients calculated as:
I a,c,e a,c,e
[ JI Li
[ l a,c,e
[El I a,c,e
]
I a,c,e a,c,e ace a,c,e a,c,e
[LI I
] and and [I ]I a,c,e a,c,e where
[I ] and
[LI )) a,c,e The variables variables in the equation are:
E P = Effective Effective elastic elastic modulus modulus forfor in-plane loading in in-plane loading the pitch in the pitch direction, direction, E: = Effective Effective elastic elastic modulus modulus forfor loading loading in in the the thickness thickness direction, direction, v;vp = Effective Effective Poisson's ratio for in-plane loading in the thickness thickness direction, Up =
G; Effective Effective shear modulus for in-plane in-plane loading in the pitch direction, GG z* = Effective transverse shear loading, Effective shear modulus for transverse If; Ed = Effective shear modulus Effective shear modulus forfor in-plane in-plane loading in the diagonal diagonal direction,
-* = Effective VVdd Effective Poisson's ratio for Poisson's ratio for in-plane in-plane loading loading in the diagonal diagonal direction, direction, and, v = Poisson's Poisson's ratio ratio for the solid material, material, EE = Elastic modulus of solid material, Elastic modulus of solid material, yRz YRZ = Transverse Transverse shear shear strain strain rRz TRZ = Transverse Transverse shear shear stress,
[D]
[D] = Elasticity coefficient Elasticity coefficient matrix matrix required required to to define define the anisotropy of the material.
the anisotropy material.
WCAP- 17071-NP WCAP-17071-NP April 2009 Revision 00 Revision
6-21 Table 6-6 6-6 Summary ofH*of H* Millstone Millstone Unit 3 Analysis Mean Input Input Properties Plant Name Name Millstone Millstone Unit 3 Plant Alpha NEU NEU Plant Analysis Type Leg Hot Leg SG Type F Input Value Value Unit Reference Reference Accident Temperature Inputs Accident and Normal Temperature NOP Thot Thol __--] a,c,e a,c,e of oF PCWG-06-9 NOP TIow T\ow of OF PCWG-06-9 SLB TS AT~T of OF 1.3F 1.3F SLBCH~T SLB CH AT of OF 1.3F 1.3F Shell ~T AT OF OF PCWG-06-9 FLB Primary AT~ T Hi of OF 1.3F 1.3F FLB Primary ~ ATT Low of OF 1.3F 1.3F Primary AT SLB Primary~ T of OF 1.3F 1.3F SLB Secondary ~ ATT OF OF 1.3F 1.3F Secondary Shell ~ AT T Hi OF OF 1.3F 1.3F Secondary Shell ~ AT T Low of OF 1.3F 1.3F Cold Leg ~TAT of OF PCWG-06-9 PCWG-06-9 Hot Standby Temperature Temperature '-- - of OF PCWG-06-9 PCWG-06-9 Operating Pressure Input Operating Input Faulted Faulted SLB Primary Pressure Pressure Faulted FLB Primary Pressure IL l~ a,.,
3 ,C,C psig psig 1.3F 1.3F 1.3F 1.3F Normal Primary Pressure Normal Primary 2235.0 2235 .0 psig psig PCWG-06-9
- - a,c,e Cold Leg AP~P a,C,e psig PCWG-06-9 NOP Secondary Secondary Pressure Pressure - psig PCWG-06-9 pSlg PCWG-06-9 Low Low NOP Secondary Secondary Pressure Pressure - Hi _ psi_
psig PCWG-06-9 Faulted Secondary Faulted FLB Secondary psig 1.3F Pressure pSlg 1.3F Faulted Secondary Faulted SLB Secondary psig 1.3F Pressure pSlg 1.3F WCAP- 17071-NP WCAP-17071-NP April 2009 Revision Revision 00
6-22 Table 6-7 List of SG Models Models and H* Plants Plants With Tubesheet Support Ring Structures General Plant Alpha SG Model TS Support Ring? Arrangement Arrangement Drawing Drawin2 a,c,c a,c,c Braidwood -2 Braidwood - 2 CDE D5 _____,__ c 1103 J99 Sub 3 Byron - 2 Byron-2 CBE D5 1103J99 Sub 3 1103J99 SAP - Use Callaway (SCP)
(SCP)
Creek-- 2 Wolf Creek SG Drawings F 1104J54 Sub 2 1I04J54 PSE - Use Seabrook -2 Seabrook (NCH) SG SG Salem--
Salem- I1 Drawings F 1104J86 Sub 9 1104J86 Surry ~ I1 Surry- VPA*** 51F 1105J29 Sub 3 II05J29 Surry - 2 VIR*** 51F 1105J29 Sub 3 1105129 Turkey Point-4 Point - 4 FLA*** 44F 1105145 Sub 3 1105J45 Millstone - 33 Millstone NEU F 1182J08 Sub 8 1182J08 Comanche Comanche Peak - 2 TCX D5 1182J16 Sub I1 1182Jl6 Vandellos Vandellos - 2 EAS F 1182J34 Sub I 1182134 Seabrook - 1 Seabrook-I NAH F 1182J39 Sub 3 1182139 Turkey Point-Point - 3 FPL** 44F 1183J01 Sub 2 1183101 Catawba - 2 Catawba- DDP D5 _ 1183J88 Sub 2 1183J88 Vogtle - II GAE F 1184J31 Sub 13 1184131 Vogtle - 2 GBE F 1184J32 Subl 1184132 Subl Point Beach - 1 I WEP** 44F 1184J32 Sub I1 1184132 Robinson Robinson 2 CPL** 44F 6129E52 Sub 3 6129E52 Indian Point - 2 IPG 44F 6136E16 Sub 2 6136EI6
- Model 44 F - These original SGs have been replaced.
- Model 51F - These original SGs have been replaced.
- Mode151F WCAP-17071-NP WCAP-17071-NP April 2009 2009 Revision 00 Revision
6-29 6-29 Table 6-8 Conservative Conservative Generic NOP Pressures and Temperatures Temperatures for 4-Loop Model F (These (These values do not exist in operating operating SG and are produced by examining examining worst-case comparisons. )
comparisons.)
Normal Operating, Operating, Bounding Secondary Surface Temperature Temperature a,c,e ace Primary Surface Primary Surface Temperature Cold Leg Hot Leg Primary Primary Pressure Cold Leg Hot Leg Secondary Pressure End Cap Pressure Structural Thermal Condition Structural Condition Reference Reference Temperature Table 6-9 Generic NOP Low T. Tavg Temperatures for 4-Loop vg Pressures and Temperatures 4-Loop Model Model F O~erating, Low T.,,
Normal Operating, T.v~
Secondary Surface Secondary Temperature Surface Temperature .....
a,c,c Primary Surface Temperature Temperature Cold Leg Hot Leg Primary Pressure Cold Leg Hot Leg Secondary Pressure Secondary End Cap Pressure Structural Thermal Condition Structural Condition Reference Reference Temperature Table 6-10 Generic Generic NOP High T. T.vg vg Pressures Temperatures for 4-Loop Pressures and Temperatures 4-Loop Model F Normal Operating, Operating, High T,vl!
Tavu _ _ _ _ _
a,c,e Secondary Surface Temperature Temperature .....
Primary Surface Surface Temperature Cold Leg Leg Hot Leg Primary Pressure Cold Leg Leg Hot Leg Secondary Pressure End Cap Pressure Structural Thermal Condition Thermal Condition Reference Temperature Reference WCAP- 17071-NP WCAP-1707l-NP April 2009 Revision Revision 0
6-30 6-30 Table 6-11 Generic SLB Pressures and Temperatures Temperatures for 4-Loop 4-Loop Model F Main Steam Line BreakBreak a.c.e a,c,C Secondary Surface Temperature Secondary Temperature Primary Surface Temperature Primary Surface Temperature Leg Cold Leg Hot Leg Primary Primary Pressure Cold Leg Hot Leg Seconda~
Secondary Pressure End Cap Pressure Structural Thermal Condition Reference Temperature Reference Temperature Table 6-12 Generic Temperatures for 4-Loop Generic FLB Pressures and Temperatures 4-Loop Model F Break Feedwater Line Break aLe Secondary Surface Secondary Surface Temperature Primary Primary Surface Temperature Surface Temperature Cold Leg Hot Leg
+
Primary Pressure Cold Leg Hot Leg Secondary Pressure End Cap Pressure - i Condition Structural Thermal Condition Reference Temperature Reference Temperature [II Table 6-13 Conservative Conservative Generic Temperatures for 4-Loop Model F Generic SLB Pressures and Temperatures (These (These values do not exist in operating operating SG and are produced by examining examining worst-case comparisons.)
comparisons. )
Main Steam Line Break, High Temp Temp Temperature a,c,e a,c,c Secondary Surface Temperature Secondary Surface Temperature Primary Surface Temperature Cold Leg Leg Hot Leg Leg Primary Pressure Cold Leg Hot Leg Secondary Secondary Pressure End Cap Pressure Pressure Structural Structural Thermal Condition Reference Temperature Reference WCAP-17071-NP WCAP-17071-NP April 2009 Revision Revision 0
9-24 9-24 Table 9-1 Table 9-1 Reactor Reactor Coolant Coolant System System Temperature Temperature Increase Increase Above Above Normal Normal Operating Temperature Associated Operating Temperature Associated With Design Design Basis Basis Accidents (References 9-12 and 9-13)
(References 9-13)
Steam Line/Feedwater Steam LinelFeedwater Locked Locked Rotor (Dead Locked Rotor (Active Control Rod Ejection Line Control Rod Ejection Line Break Break Loop)
Loop) Loop)
Loop)
SG SG Type Type SG Hot SGRot SG SG Cold Cold SG Hot SGRot SG SG Cold Cold SG Hot SGRot SG SG Cold Cold SG Hot SGRot SG SG Cold Cold Leg Leg Leg Leg (OF)
(OF) Leg Leg (OF)
CF) Leg Leg (°F)
(OF) Leg (OF)
(OF) Leg (OF)
(OF) Leg (OF)
(OF) Leg (°F)
CF) (OF)
(OF) r-- -
Model FF Model a,c,c a,c,c Model Model D5 D5 Model 44F Model44F Model 51F Model51F
- Best Best estimate estimate values values for for temperature temperature during during FLB/SLB FLB/SLB are are used used as as discussed discussed in in Section Section 9.2.3.1.
9.2.3.1.
WCAP- 17071-NP April 2009 WCAP-17071-NP WCAP-17071-NP April April 2009 2009 Revision 0 Revision 0
9-25 Table 9-2 Reactor Coolant Systems Peak Pressures During Design Basis Accidents (References (References 9-12 and 9-13)
SG Type Steam Line Break Feedwater Line Locked Rotor Control Rod Ejection Steam Line Break Feedwater Line Locked Rotor Control Rod Ejection SGType (psia) Break (psia) (psia) (psia)
Model D5 ModelD5 a,c,c Model F ModelF Model 44F Model44F Model 51F Model51F WCAP-17071-NP WCAP-17071-NP April 2009 Revision 0 Revision
9-26 Table 9-3 Model F Room Temperature Temperature Leak Rate Test Data I F 9 Test No.
No. EP-31080 I EP-30860 Test EP-30860 I EP-29799 I EP-30860 EP-29799 I EP-31330 EP-31320 I EP-31330 I EP-31320 EP-31300 EP-31300 Collar Bore P Ja,c,c
]a,c,c Collar Bore Dia. (in.)
Dia. (in.) [
Test Pressure Leak Rate (drops per minute - dpm)
Differential (psi) r-Fa... - a,c,c 1000 1910 1910 2650 2650 3110 3110 '--
AP M Ratio Leak Rate Ratio (normalized to initial AP)
~P) Average LR Ratio
-I - a,c,c a,c,c 1
1.91 2.65 3.11 3.11 - -
WCAP-17071-NP WCAP-1707l-NP April 2009 2009 Revision 0 Revision
9-27 Table 9-4 Model F Elevated Temperature Temperature Leak Rate Test Data i F 9' 9' F 0 00 0 0 ________ _________________
00 0
00 00 0 0 0 ~ 0 0 0 C:ý ~ 0 00 00 00 C,
00 00 '-0 '-0 ~ ~ 0 0 0e¢) 0 r'--
0 00 0CIO 00 0o 00 r- r- oo 00q 00q 00 M M Test No. 0 0 ~
t'N ~ N r',
N m, M M M M N N M M M M 1 1 1 1 1 1 1 Oz.,
1 1 0... 0... 0... 0... 0... 0.. 0... 0... 0... 0...
[
W W W W W W W W W W a,c,c a,c,e Collar Bore Dia. (in.)
(in.) [
__ ]
Test Pressure Differential Differential (psi) Leak Rate (drops per minute -dpm)
-dpm)
- - a,c,e 1910 1910 2650*
2650{
3110 3110 AP tlP Ratio Ratio Leak Rate Ratio (normalized (normalized to initial tlP)
AP) Average Average LR Ratio a,c,e a,c,e I
1.39 1.39 1.63 WCAP- 17071-NP WCAP-17071-NP April 2009 Revision 0 Revision
9-28 Operating Conditions Table 9-5 H* Plants Operating (1)
Conditions Summary (\)
Pressure Pressure Pressure Differential Differential Differential Differential Across Across the Tubesheet Temperature Temperature Temperature Temperature Temperature Temperature Temperature Temperature Across the Number Across the the Tubesheet (psi)
Cold Leg (F) Tubesheet Plant Name SG Type of of (F)
Hot Leg (F) Cold Leg (F)
Cold Leg (F) Hot Leg (F)
Hot Leg (F) Cold Leg (F)
Tubesheet (psi)
Loops High Tavg High Tavg High Tavg High Tavg Low Low Tavg Tavg Low Tavg Low Tavg (psi) Low Tavg (psi) Low Tavg High Tavg Tavg a,c,c r- -
Byron Unit 2 and D5 4 Braidwood Braidwood Unit 2 Salem Unit 1 F 4 Robinson Unit 2 44F 3 Vogtle V ogtle Unit 1 and 2 F 4 Millstone Unit 3 F 4 Catawba Unit 2 D5 4 Comanche Peak D5 4 D5 4 Unit 2 Vandellos Vandellos Unit 2 F 3 Seabrook Seabrook Unit 1 F 4 Turkey Point Units 44F 3 44F 3 3 and 4 Wolf Creek WolfCreek F 4 Surry Units 1 and 2 51F 3 Indian Point Unit 2 Indian 44F 4 Point Beach Unit 1 44F 2 (1) The source of all temperatures temperatures and pressure pressure differentials differentials is Reference 9-21.
Reference 9-21.
April 2009 WCAP-17071-NP WCAP-17071-NP April 2009 Revision 00 Revision
9-29 Table 9-6 H* Plant Maximum Pressure Pressure Differentials Differentials During Transients Transients that Model Primary-to-Secondary Primary-to-Secondary Leakage Leakage (\)
(1)
FLB/SLB Pressure Pressure Locked Locked Rotor Pressure Pressure Control Rod Ejection Normal Operating Operating Pressure Plant Name Differential (psi) Differential (psi) Pressure Differential (psi) Differential High Tavg (psi)
Differential (psi) Differential (psi) Pressure Differential (psi) Differential High T avg (psi)
Byron Unit 2 anda,c, r- - a,c,c Byron Unit 2 and Braidwood Unit 2 Salem Unit Salem Unit I1 Robinson Unit 22 Robinson Unit Vogtle Unit 1I and Vogtle Unit and 22 Millstone Millstone Unit Unit 33
.Catawba Catawba Unit 2 Comanche Comanche Peak Unit 2 Vandellos Unit 2 Seabrook Unit 1 Turkey Point Units 3 and 4 Wolf Creek WolfCreek Surry Units 1 and 2
~
Indian Point Unit 2 Beach Unit 1 Point Beach '-- -
(1) The source of all pressure differentials is Reference 21.
allpressure 21.
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9-30 9-30 Table 9-7 Final H* H* Leakage Analysis Leak Rate Factors Transient Transient SLB/FLB SLBIFLB Locked Locked Rotor Rotor Control Rod Ejection Ejection FLB- SLB/FLB VRT Leak Leak vR3J VR Leak Adjusted Adjusted 3 SLBIFLB VR3 - i SLBINOP SLB/NOP VR VR3@ @ Leak Rate LRINOP LR/NOP Rate Adjusted CRE/NOP CREINOP @ Rate CRELRF CRE LRF Plant Name Leak Rate @
Plant Name ~PRatio AP Ratio 2672 psia psia( ~PRatio AP Ratio @ Factor LR LRF1 LRLRFI ~P AP Ratio 3030 3030 Factor Factor(LRF) 2711 psia (High Tav,)2 (High TaPl)' Factor(LRF) 2711 psia (LRF) psi psiaa (LRF) r- -* a,c,e a,c,e - - a,c,e a,c,e Byron Unit 2 and 1.93 Braidwood Unit 2 Braidwood Salem Unit 1 1.79 1.79 Robinson Unit 2 1.82 1.82 Vogtle Unit 1I and 2 2.02 Millstone Unit 3 2.02 Catawba Catawba Unit 2 1.75 1.75 Comanche Comanche Peak Peak 1.94 1.94 Unit 2 Vandellos Unit 2 1.97 1.97 Seabrook Unit 1 2.02 Turkey Turkey Point Units 33 1.82 and 44 and Wolf Creek WolfCreek 2.03 2.03 Surry Units I1 and 2 1.80 1.80 Indian Point Unit 21.75 2 1.75 Point Beach Unit 1IIL 1
-_1.73 1.73 1 L- -
- 4. Includes Includes time integration leak rate adjustment adjustment discussed discussed in Section 9.5.
- 5. The larger of the AP's
~P's for SLB or FLB is used.
- 6. VR - Viscosity Ratio Ratio WCAP-17071-NP WCAP-17071-NP April 2009 April 2009 Revision 00 Revision