ML17250A511
| ML17250A511 | |
| Person / Time | |
|---|---|
| Site: | Ginna  |
| Issue date: | 06/30/1980 |
| From: | Hutton J, Yoose W ROCHESTER GAS & ELECTRIC CORP., WESTINGHOUSE ELECTRIC COMPANY, DIV OF CBS CORP. |
| To: | |
| Shared Package | |
| ML17250A510 | List: |
| References | |
| EWR-2512, NUDOCS 8008190367 | |
| Download: ML17250A511 (67) | |
Text
CRITERIA DOCUNEiVT.
R. E.
GINNA NUCLEAR POWER PLANT PIPING SEISMIC UPGRADING PROGRAM WESTINGHOUSE ELECTRIC CORPORATION Pittsburgh, Pennsylvania Document Number EWR-2512 Revision Number 0
Prepared by:
c~~
Project Engineer, Westinghouse Date Prepared by:
Project Engineer, hilbert Associates Date Approved by:
g -gd Mec anzcal En ineer, Rochester Gas 6 Electric Date
/
Approved by:
Manage Mechanical Engineering, RGSE 1
Date Criteria Document EWR 2512 8008, g Os@'P:
Page 1
Revision 0
Date 4/2/80
C
1.0 So:-,mar~Description nf the Pro ram Summary 1.1.1 The purpose of pi ping systems and to provide tions, the ISI this program is to upgrade certain seismic at Gi ma Station to more current requirements a seismic data base for use witn mcdifica-
- program, and i<RC requests for information.
1.1. 2 1.1.3 1.1.4 1.1.4.1 1.1.4.2 1.1.4. 3 1.2 1.2.1 1.2.1.1 Attachment 1 to this document is the minutes of the meeting between RG5"-
and the HRC outlining the scope,
- purpose, and schedule of'he program.
Systems Included Portions of the following piping systems are to be included in this program:
t Reactor 'Coolant System Hain Steami Main Feedwater Auxiliary Feedwater Safety Injection Residual Heat Removal Containment Spray Chemical and Volume Control 1)
Auxiliary Spray 2)
Letdown (3)
Seal Mater (4)
Char ging Steam Generator Blowdown Service Mater Component Cooling Piping Analysis Scope Section 1.2.2 defi nes the main lines of each system
~'which are to be re-analyzed and re-supported as necessary.
Attachment 2 to this document defines the 'lines included in the program and the criteria used t'o select the lines.
All main line and branch piping, valves,
- nozzles, and sup-portss shall be evaluated against the criteria established for the program.
Program Func tional Criteria Criteria for Selection of Lines in the Piping Upgrade Program Only piping that is considered seismic Category I as identi-fied by the color coded PE ID's in Appendix A of the Ginna Station gA Manual shall be included.
Criteria Document EMR 2512 Page 2
Revision' Date 4/2/80
1.2.1.2 Hain runs of piping '.ncluded shall be based on the following criteria.
1.2.1.3 1.2.1.4 1.2.1.5 1.2.1.6 hain runs of piping which are 2 1/2 inch and larger and crit-ical 2 inch piping.
hain runs which provide the fluid flow path to/or fl om equip-ment required for safe shutdown and LOCA mitigat'."n based on
'SEP.
Equipment does -not include instrum ntation.
Selected additional main runs not included in 1.2.2 but which are a primary pal t oi the systems included in the upgrade program.
Branch lines included shall be based on the following criteri a.
1.2.1.6.1 Branch lines shall be included'n the analyses as necessary to determine the local effec.s of the branch lines on the main runs and to assure adequate flexibilityexi'sts in the branch line to prevent local.overstress in the branch due to main run displacements.
1.2.1.6.2 Branch lines whose section modulus is greater than 15/ of the main run section modulus shall be included in the analysis for an appropriate distance and/or number of supports.
1.2.1.6.3 Branch lines whose section modulus is less thn 15/ of the main run section modulus
'do not need to be explicitly included in the analysis.
1.2.2 1.2.2.1 1.2.2. 2 Lines Selected Reactor Coolant System
{EFD 33013-424 Rev.
D)
Primary Loop Surge Line Pressurizer Spray Lines From the Cold Legs to the Pressurizer l1ain Steam (EFD 33013-534, Rev.
1)
The 30" lines from both SG's through. the penetrations and up to the HSIV's.
1.2.2.3 Inlet piping up to safety and relief valves.
fiain Feedwater (EFD 33013-544, Rev. 4)
The 14" lines from the SG's through the penetrations and up to check valves 3992 and 3993.
Criteria Document ERR 2512 Page
.3 Revision 0
Date 4/2/80
1.2.2.4 1.2.2.5 1.2.2.6 Auxi 1 i ary Feedwater (EFD 33013-544, Rev. 4j The discharge lines from the two motor dri ven pumps and the turbine driven pumps up to the main feedwater'-connections.
The condensate and service water suction lines from the pumps to check valves
- 4014, 4017, 4018 and to valves 4013,
- 4027, 4028.
Safety Injection (EFO 33013-425, Rev.
C)
(EFD 33013-432, Rev.
B)
The 10 inch SI accumulator discharge lines to the cold legs.
SI pump suction lines from the RllST through 896 ARB and 825 AEB to the three pumps.
The SI pump discharge lines from the three pumps to the SI accumulator discharge lines and to the two hot leg con-nections.
The boric acid lines from the boric acid storage tanks to the SI pump suction line.
The 4 inch alternate SI suction line from valves 1816 AEB to the pump.
The 10 inch low head SI suction from the RWST to valve 854.
The 6 inch/8 inch header from the RMST to valves 857 A, B, and C.
The S inch suction lines from contain sump B to valves 850 A5B and the 6 inch branch lines to valves 1S10 AEB.
The low head safety injection lines from valves 852 A5B to the RCS.
Residual Heat Removal (EFD 33013-435, Rev.
B}
(EFD 33013-436, Rev.
E)
The 10 inch suction lines from the loop A hot leg to the two RHR pumps.
From valves 850 AFB to the pumps.
From valve 854 to the suction header.
The two pump discharge lines through heat exchangers and to the comnon 10 inch return.
The 10 inch return through penetration P111 and to the B cold leg.
Criteria Document ELJR 2512 Page
.4 Revision 0
Date 4/2/80
< i
The discharge cross-connect including valves 709C and D.
The heat exchanger by-pass line including valves 712 AEB.
The two lines from the RHR heat'exchanger outlets to valves 857 AEB and 1816B.
The recirculation line from the RHR return through valve 8228 to the RHR suction line.
The two lines from the RHR return to valves 852 AKB.
1.2.2.7 Containment Spray (EFD 33013-436, Rev.
E)
(EFD 33013-435, Rev.
B)
I The tvo suction lines from RAST header to the spray rings.
The two pump discharge lines and spray rings.
The two eductor lines from the pump discharges to the pump suctions.
The spray additive lines from the tank through 836 AE:B and to the two eductors.
1.2.2.8 Chemical and Volume Control, (EFD 33013-426, Rev.
2, 433, Rev.
0)
(EFD 33013-427, Rev.
B, 434, Rev.
2)
The auxiliary pressurizer spray line from the connection at regenerative heat exchanger outlet line to the pressurizer spray line.
The letdown line from the RCS through the regenerative heat exchanger, through the non-regenerative heat exchanger, through valve TCV 145 to the volume control tank.
The 4 inch header from 'the VCT and the 3 inch suction lines to the three charging pumps.
The three charging pump discharge 1".nes to the acoustic filter.
The 2 inch charging lines from the acoustic filter through the regenerative heat exchanger to both the hot and cold leg connections.
The 3 inch seal water header from the acoustic filter and the two 2 inch lines to the RCP seals.
The 2 inch seal water return lines from the RCP seals and the 3 inch return header thrugh the seal water heat exchanger to Criteria Document E>lR 2512 Page 5
Revision 0
Date 4/2/80
1.2.2.9 1.2.2.10 the VCT.
Includes 3/4 inch piping through flow transmitters
- 175, 176,
- 177, and 178.
The 4 inch line rom the RNST through valves LCV 1! 2B and 358 to the charging pump suction header.
Steam Generator Blowdown
{EFD 33013-522,. Rev.
A)
The.tvo 2 incn lines from the SG's through the penetrations to the isolation valves.
Service Hater System (EFD 33013-529, Rev.
6)
The inlet piping to both diesel generators including the cross-connection between the diesels, the 16, 14, and 10" supply to the Turbine Building up to valve 4613.
The outlet piping i rom both diesel generators to an anchor point outside the diesel generator room.
The 20 inch supply lines and header i nside the Auxiliary Bui 1 ding.
The 18, 14, and 6" supply lines from the 20 inch header to the two component cooling water heat exchangers and the spent fuel pool heat exchanger.
The normal discharge lines from the component cooling water heat exchangers and the spent fuel pool heat exchangers and the spent fuel pool heat exchanger including the 20 inch discharge insi de the Auxiliary Building.
The 3 inch supply and normal discharge headers to and from the SIS pumps and equipment coolers in-the Auxiliary Building (includes piping through valves
- 4738, 4739, and 4739A.)
The 16 and 14 inch supply headers inside the Intermediate Building.
Including piping through valves
- 4040, 4623,
- 4639, and 4756.
The 10 i nch supply to the Turbine Building up to valve 4614
'he 4 i nch supply lines to the AF>l pumps.
The 2', inch and 8 inch supply and discharge lines to and from the 1A, 1B, 1C and 1D Containment Ventilation Cooling Coils and Fan Yotors, The 2-'; inch supply and discharge lines for the reactor com-partment coolers, including piping through valves
- 4625, 4626, and 4624.
Criteria Document Et!R 2512 Page 6
Revision 0
Date 4/2/80
The 4 inch supply to the air conditioning water chillers up to the isola ion valves 4663 and 4733.
- 1. 2. 2.11 1.2.3 1.2.3.1 The common discharge header for the ventilation coolers up to an anchor point outside the Intermediate Building.
Component Cooling plater (EFD 33013-435, Rev.
B, 436, Rev.
E)
. The 14 suction header and 10 inch suction lines to the CC'i'umps.
The CCRC! pump discharge lines to the CCW.heat exchangers.
The 4 i nch and CC~rl surge tank line.
The 10 and 14 inch supply headers out of the CCM heat exchangers.
The 10 and 14 inch supply lines to both residual heat exchangers.
The 10 and 14 i nch return lines from the residual heat exchangers to the CCH pumps suction header.
The 2 inch supply and return lines to the RHR pump cooler s.
The 14 and 8 inch supply and return headers servicing the reactor coolant pumps and reactor supports.
The 3
and 4 i nch supply and return line to both reactor cool-ant pump motors.
The 6 inch supply and return lines for the reactor supports from the 2 inch headers to penetrations 130 and 131.
The 2 inch supply and return lines for the excess letdown heat exchanger from the 8 inch header to penetrations 124 and 126.
The 6, 4, and 2 inch supply and ret'urn lines for the non-regenerative heat exchanger and the seal water
- heat, exchanger.
The 2 inch supply and return lines for both containment spray and both safety injection pumps.
Floor Response Spectra I,
Gilbert Associates shall prepare floor response spectra and structural displacement data based on current NRC criteria.
The analysis model shall consider interaction between all the various structures.
Criteria Document El(R 2512 Page 7
Revision' Date 4/2/80
1.2.3.2
Response
spectra and oisplacements shall be developed for the following structures:
Containment Containment Interior Auxi 1 i ary Bui1 ding Intermediate Building Control Building Diesel Generator Building Turbine Generator
- See Note 1
Facade See tlote 2
Notes 1.
Only as needed for portions of safety related piping and safety related equipment in the Turbine Building.
2.
Only if needed for i~)ain Steam and Feedwater Piping.
1.2.4 Schedule 1.2.4. 1 The current schedule to complete the project in two phases.
Phase 1:
Complete the piping analysis and installation of piping supports inside containment by the end of the 1981 ref ue ling ou tag e.
Phase 2:
Complete the piping analysis and installation of piping supports outside containment by the end of the 1982 refueling outage.
1.2.4.2 1.2.5 1.2.5.1
'1.2.5.2 1.2.5.3 A detailed schedule shall be developed to permit planning, monitoring, and control of the project-activities.
Westinghouse Responsibi 1 ities Westinghouse will have the following re'sponsibi lities:
- A The technical
- lead, as well as project coordination and schedule responsibility for the analysis and redesign program.
The technical lead to assure the correct a,.d required infor-mation is obtained to perform the analyses.
Consult RGKE and Gilbert Associates (GAI) and request response spectra.
1.2.5.4 1.2.5.5 Development of criteria document Perform normal and seismic stress analysis of the required piping systems.
Criteria Document EWR 2512 Page 8
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1.2.5.6 1.2.5.7 1.2.5.8 1.2.5.9 1.2.5.10 1.2. 6 1.2.6.1 1.2.6.2 1.2.6.3 1.2.6.4
- l. 2. 6.5 1.2.6.6 1.2.6.7
- 1. 2. 6.8 1.3 Gilbert Gi lbert Provide seismic Develop Responsibilities
>Iill have the following responsibilities.
Westinghouse the required response spectra and displacem nts.
the required piping isometric drawings.
Provide Westinghouse the required analysis data.
Develop stiffness information and characteristics for existing supports'omplete the additional support design and analysis as'efined by the interface between Westinghouse and Gilbert.
(e.g.,
support embedment, load analysis, development of pro-curement data).
Evaluate existing supports for capability of carrying piping loads and modify as required.
Evaluate existing structures for capabilitv of carrying piping loads and modify as required.
Provide final "as built" drawings of piping, supports and structures and completed analysis isometrics.
General Data Requirements Develop support design information (stiffness, gaps and general layout, etc.) for additional supports required.
Develop detailed stress report.
Define stiffness 11miis for defining r'igid supports.
Define an analytica'1 method for handling common pipe supports.
Oe ine criteria for seismic supports, i.e.,
- lockup, and support gap tolerances.
1.3.1 For the seismic upgrading program, it is necessary to obtain the information required to perform the piping system analy-ses.
ln this section the information required, the proce-dures
- used, the r quirements pertaining to field verifica-
- tion, and the information,required on the isometrics is defined; Field tleasurements and Field Survey Criteria Document EWR 2512 Page 9.
Revision Date 4/2/80
1.3.1.1 Piping Information 1.3.1.2 1.3.1.3 The actual con'iguration of the pioing system will be com-pared to the piping "esign drawings noting pipe size, loca-tions of supports,
- valves, insulation thickness, and branch connec.ions.
Fit ings and vields are located where insulation does not interfere.
Additional fittings and 'rields are assumed to be located per the existing drawings.
Types of welds, fittings, and insuiation are assumed to be per the applicable speci ications.
Equipment support locations are assumed to be per the equipment drawing or "as-built" when requested by vlestinghouse.
Drawings were made for any pipe routing not in agreement with the design drawings.
Dimen-sions along the axis of the pipe were recorded to + 4".
All available valve tag informat'.on was recorded, dimensions to end of operator or handwheel
- recorded, and orientation of the operator or handwheel noted.
This information was used to generate as-built p.'ping and isometric drawings and to deter-mine valve type,'eight, c.g.
and manufacturer.
Support As-Built The actual support design viill be compared to the support design dravring.
A comparison is made of material sizes and
- lengths, weld sizes and pipe to support clearances.
Any discrepancies are noted.
All existing supports in the field are tagged with the original design support number or given a
nevi "N" number if no design drawing exists.
As-built support drawings for each support are then made from the data gathered in the field.
For dimensions greater than one inch, the tolerance is + 1/8, inch, for dimensions less than one inch, the tolerance is + 1/16 inch.
Unavailable Information 1.3.2 1.3.2.1 Any information that is unavailable, such as spring can sizes or valve data due to missing tags or support membe.
s embedded in concrete, is documented and an assumption made based on all available data.
If the physical configuration and dimen-sions match the design drawing, it is assumed the item was installed in accordance with the design draving.
Supplemental Data Requirements Given below is a summary of the information, supplementing the piping isometrics, required by llestinghouse to perform the piping analyses.
1.3.2. 1a Piping material and sch dule.
1.3.2. 1b Piping insulation size and weight including metal jackets.
Criteria Document EMR 2512 Page 10 Revision 0
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1.3.2.1c 1.3.2.1d 1.3.2.1e Ope. ating/design temperatures and pressures in the piping systems.
Definition of analysis information for fittings (e.g.,
- tees, elbows, etc.)
- flanges, valves, and nozzles.
t!aster valve 1 i st.
1.3. 2.1f 1.3.2.1g 1.3.2.1h
- l. 3. 2.li vendor's catalogs associ ated with pipe supports (e.g.,
- hangers, snubbers, etc.).
Hanger index.
Data pertaining to supports from which stiffness and stresses and allo vable loads can be determi ned.
Definition of boundary conditions to be used in the analysis associated with penetrations (e.g.,
anchor fixed/flexible, etc.).
- 1. 3: 2.1j Suppor t Drawi ngs.
1.3.2.1k General arrangement and layout drawings showing concrete.
1.3.2.11 Equipment support drawings.
1.3.2.1m 1.3.2.1n Drawings defining size, material, etc., for equipment (e.g.,
- tanks, valves, heat exchangers, etc.)
which must be modeled in the piping systems.
Appurtences and integral supports and the associated stress indices.
1.3.2.2 1.3.2.3 Inhere information is lacking, undecipherable or otherwise
~ inadequate, photographs, field measurements, similarity com-parisons or other means shall be taken to assure that the analysis information used is correct.
Where this is not
- possible, a range should be established which can be used to study the effect of the' nadequate information on the analy-sis.
The analyses performed should be based on "as-built" data as verified from field measurements.
All pipe nozzles which are part of the analysis scope are to be identified giving location, size, nozzle type, and thick-ness.
1.3.3 1.3.3.1 Isometric Requirements Isometrics will be prepared reflecting "as-built" condi-tions.
They should be certified-for-analysis.
The informa-tion which wi'll be contained on the drawing will be:
Criteria Document ERR 2512 Page 11 Revision 0
Date 4/2/80
1.3.3.1a 1.3.3.lb l.3.3. lc 1.3.3.1d Location, type, and directionality oi all suppor'ts.
Location and type of all shop and field welds.
This informa-tion is not always available, because it is covered by insulation.
it is noted on the isometrics when available.
See Section. 1.3.1.1.
Pipe size,
- schedule, material, and insulation weight.
Temperature and pressure for design and normal (operating) conditions.
1.3.3.1e Location and type of all anchors and branch terminal points.
1.3.3.1f Piping classification boundaries.
1.3.3.1g 1.3.3.1i 1.3.3.1j Yalve types and locations with associated valve identifica ion numbers.
Definition of symbols and units used.
Global coordinates which can be used to check closure and provide references, attachment points.
(This will be shown on piping orthographic drawings).
1.3.3. lk Reference north direc.ion.
1.3.3. ll Location and size of all appurtences welded to pipe.
Criteria Document BlR 2512 Page 12 Revision 0
Date 4/2/80
2.0 Referenco Documents A.
USAS B31. 1 Code 1967 B.
ANSI B31.1 Code Summer 1973 Adenda C.
ASME Section III Appendix XVII D.
ASME Section III Subsection NF F.
AISC Specification For Design, Fabrication, And Erection of Structure Steel, or Buildings, 6th Edition.
USNRC Regulatory Guide 1.60 - Damping Values G.
USNRC Regu'latory'Guide 1.61 - Damping Values H.
USNRC Regulatory Guide 1.92 - Combination of Modal Responses I.
USNRC Regulator y Guide 1.122 J.
USNRC Regulatory Guide 1.124 - Service Limits and Loading Combinations.
K.
USNRC IE Bulletins 79-02 Pioe Support Base Plate Design Using Concrete Expansion Anchor Bolts 3/8/79 Rev.
1, 6/21/79 Rev.
2, ll/8/79 79-04 Incorrect rhights for Swing Check Valves Manu-factured by Velan Engineering Corp.,
3/30/79 79-07 Seismic Stress Analysis for-Safety Re'lated Piping 4/14/79 79-14 Seismic Analysis for As-Built Safety Related Piping Systems 7/2//9 Revision 1, Suop]ement 1
8/15/79, Supplement 2
9/7/79 L.
ACI-349 Appendix B - Embedments M.
Hilti Cri.eria for Component Su~port Embedments N.
RGE Analysis and Design Conditions Document 0.
Dames 8 Moore Site Evaluation Study Proposed Brookwood Nuclear Power Plant P.
Dames 8 Moore Supplementary Fouiidation Study Proposed Brookwood Nuclear Power Plant Criteria Document
~)JR 2512 Page 13 Revision 0
Date 4/2/80
3.0 Seismic
Response
Spectra Development 3.1 The puroose of the present dynamic analysis i~ to primarily generate floor response spectra and maximum floor displace-ments at the mass points of the-structural model to be used for upgrading of the selected piping systems at the Ginna Station.
The plan. specified horizontal and vertical seismic accelerations for the Ginna Station have be n determined as 0.08g "or Operating Basis Earthqua!<e (OBE) and 0.20g for Safe Shutdown Earthq ake (SSE).
The floor response spectra will be generated for majcr floor elevations for ihe following structures, corresponding to three orthogonal directions (one vertical and trio norizontal) for 1%,
2% and 4/ damping values for OBE and 2%,
3%, 4/ and 7% for SSE:
1.
Containment Building 2.
Containment Interior 3.2 3.3
.3 3 I 3.'uxi1 i ary Building 4.
Intermediate Building 5.
Control Building 6.
Diesel Generator Building 7.
Turbine Building If required, an additional floor response spectra at 5%
damping for OBE and SSE will be generated for the Containment Interior, Auxiliary Building, Intermediate Building and Control Building.
For the flexible floor framing system, the floor response spectra at the center of the floor will be different from those at
.he edge of the floor due to vertical input.
To include the effect of flexible floor system, the floor response spectra will be generated in a two step approach for the sp cified location when required.
Description of Structures The plant buildings are located in a relatively level meadow area with a finished grade elevation of approximately 270'-0".
The major plant sti uctures are supported on the gueenston Formation bed rock (red sandstone) or atop natural or compacted granular soils immediately above the bed rock.
The gueenston Formation is generally found at a depth of 30 to 40 feet below natura'.
grade.
Criteria Document EllR 2512 Page
'l4 Rev>sion 0
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3.3. 2 Cont ai nment Bu-1 di ng The Containment Building is founded on rock.
The bottom of the foundat i on mat el evati on is 231'8" with the deepest foundation around the reactor vessel at elevation 208'-0".
The containment cylinder is founded on rock {sandstone) and anchored by m ans of post-tensioned rock anchors i(hereby rock acts as an integral part of the containment structure.
The
~ Containment Building is isolated from other buildings.
The-Containment Building is a reinforced concrete vertical right cylinder wii:h a flat base and a hem',spherical dome.
It is 99 feet high to the spring line of the dome and has an inside diameter of 105 feet.
3.3.3 Containment Interior The containment base floor is at elevation 235'-8".
The intermediate floor and operating floor are o, reinforced concrete and supported on structural steel framing at eleva-tions 253'-3" and 278'-4" respectively.
The-structural steel box columns are supporting overhead cranes.
The top of the crane rail is at elevation 331'-0".
The crane g rder has a
bumper at each end>>hich is in contact with the containment shell.
Interior wall s are of reinforced concrete.
3.3.4 Auxi1i ary Bui 1 ding l
The Auxiliary Building is located south of the Containment Building and founded on rock.
The bottom of the foundation mat elevation is 233'-8", with the deeoest foundation for decay heat removal area at elevation 217'-0" with the sump at elevation 214'-0".
Rock elevation in this area is approxi-mately at elevation 235'0".
The west end of the superstruc-ture of the Auxiliary Building is connected with a portion of the Service Building, and on the northwest with the Interme-diatee Building.
However, the foundation of the Auxiliary Building is independent of these building foundations.
The basement floor is at elevation 235 '8".-.'he intermedi ate and operating floors are of-reinforced concrete supported on reinforced concrete walls and are at elevation 251'0" and 271'-0" respectively.
The superstructure is of braced s.ruc-tural steel framing with high and low roofs at elevations 328'-0" and 312'-0", approximately.
The high roof area has an overhead
- crane, with the top of the crane rail at eleva-tion 310'-9".
3.3.5 Intermediate Building The Intermediate Building is located. on the north and west of the Containment Building, and is founded on rock.
The west end has a retaining wall where the floor at elevation 253'-6" is supported.
The bottom of the retaining wall footing is at Criteria Document ENR 2512 P age 15 Revision" 0
Date 0/2/80
~
~
elevation 233'-6".
Rock elevation in this area is approxi-mately at elevation 239'-0".
=oundations for interior columns are on individual column footings and embedded a
minimum of 2'-0" in solid rock.,The basemen:'floor slab is of rein,orced concrete and is at elevation 253'-8".
The upper floors are of reinforced concrete supported on struc-tural steel framing.
The floors on the north of the Contain-ment Building are at elevations 278'-4", 298'-4",
and 31.='-4" with the structural steel framed roof at elevation 336'-4".
The southwest floors are at elevation 271'-0" and 293'-0" with tho structural steel framed roof at elevation 318'-0".
3.3.6 3.3.7 3.3.8 Control Building The Control Building is located adjacent to the southeast corner of the Turbine. Building and is supported by a mat foundation.
The foundation, of the Control Building is sup-ported on the natural compacted granular material.
The rock elevation in this area is approximately at elevation 240'-0".
Bottom elevation of the deepest portion of the foundation mat is at elevation 245'-4", with a structural slab supported at elevation 250'-6" with a thickened slab for column footing.
The Control Building has reiniorced concrete walls on the south and west side up to the roof elevation, while the concrete wall on the east side is up to grade level.
The basement slab is at elevation 253'-8".
T)ie intermedi ate floors are of reinforced concrete, supported on structural steel framing system and are at elevations 271'-0" and 289'-6".
The roof is of reinforced concrete supported on a structural steel truss and is at elevation 310'-4".
Diesel Generator Building The Diesel Generator Building is located beyond the northeast corner of the Turbine Building and is supported on strip and spread footings at elevation 243'-0".
The rock elevation in this area is at elevation 240'-0".
The foundation structures are supported on the natural compacted granular material.
The Diesel Generator Building has reinforced concrete walls on all four sides.
The basement floor is of reinforced con-crete slab at an elevation of 253'-8".
The roof is of struc-tural steel framing with decki ng and is at elevation 275 '10".
Turbine Building Page 16 The Turbine Building is located north of the Intermediate Building and is supported by a combination of perimeter grade beams and a structural mat.
The mat-foundation of the tur-bine generator is independent of the surrounding Turbine Building foundations.
The Turbine Building foundation is supported on the natural compacted granular material which overlays the natural rock.
Rock -elevation in this area is approximately at elevation 239'-,0".
The bottom of the perimeter column foundation mat varies from elevation 245'-3" Crii:eri a Document Revision 0
ERR 2512
~
Date 4/2/80
3.3.9 on the south side along the Intermediate Building to approxi-mately 246'-9".
The bottom of the turbine generator founda-tion mai is at elevation 243'-0".
The circulating water discharge tunn 1 is supported at elevation 242-'-2".
vlhere condensate oumps are
- located, tPe entire area is filled with lean concrete having a bottom elevation of 229'-8".
Area between the turbine oenerator foundation
.and the perimeter column mat foundatioh is s.pported on compacted granular
~material with the bottom o,
the mat at elevation approxi-
'ately 251'-6".
The basement floor is rein orced concrete and is at elevation 253'-6".
The mezzanine and operating floors are reinforced concrete and are supported on struc-tural framing at elevation 271'-0" and 289'-6" respectively.
The superstructure is a braced structural steel frame, with the roof at elevation 356'-ll 3/4".
The building has an overhead
- crane, 125T/25T capacity, with the top of the crane rail at elevation 330 0".
Service Building The Service Building is located on the west side of the Intermediate Building and is founded on compacted soil.
The bottom of the mat is approximately at elevation 252'-8" with a localized thickened mat for column footings.
The deepest foundation for the sump is at elevation 247'-3".
Natural compacted granular soil is approximately at elvation 255'-0".
The mat is supported on the east side by a retaining wall on column line 3 with the Intermediate Building.
The basement floor,is reinforced concrete and is at elevation 253'-8".
The main floor slab is reinforced concrete supported on structural steel framing and is at elevation 271'-0".
The roof is composed of structural steel framing with decking at elevation 287'-4".
The superstruc-ture is structural steel framing system with exterior block walls all around.
3.4 3.4.1 Analysis method Safety Class Seismic Category 1 Structures are analyzed using
- STARDYHE, a general ourpose linear elastic finite element program.
The analys-'s uses a modal superposition method which includes all significant modes.
The program calculates the damping v'alues for the dynamic modes involved in the analysis reflecting structural damping of various materials.
Each model is analy ed for the simultaneous application of three orthogonal statistically independent earthquake time histories for both OBE and SSE.
The horizontal earthquakes are input along the E-'8 and N-S axis of the models for all structures except the Containment Building and Containment Interior.
The horizontal input for these two structures is along their principal axes.
The absolute acceleration time histories of the structural response of a particular mass point are used to generate the floor response spectra.
Criteria Document EHR 2512 Page 17 Revision Date 4/2/80
3.4. 2 3.4. 3 3,4,4 3.4. 5 3.4. 6 3.5 3.5.1 The Containment Building and Containment Interior are modeled separately from the remaining plant structures.
The compos i t model of the remaining plant structures includes the Auxiliary Building, the Intermediate Building, the Service Building, the Turbine Building, the Control
- Building, and the Diesel Generator Building.
The maximum response due-to horizontal and vertical input are combined in accordance with the requirements of USHRC Regula-tory Guido 1.92.
Lumped mass models for the Reactor Building and other i nterconnected buildings are developed.
The mass poi nts of a
building are always chosen at the points of physical mass concentration, e.g.,
heavy floors, and include the masses of
- loors, equipment, and walls as required.
The model of the interior of the Conta-'inment Build'.ng will also include the primary loop model'i th the building structural model.
The peaks of the floor response.
spectra are broadened 15 percent on each side in accordance with USi'JRC Regulatory Gui de 1.122 to account for vari ati on in structural and soil proper ties.
Seismic Input Et Design Response Spectra The design basis earthquakes, OBE and
- SSE, response spectra for the plant are developed on the basis of USNRC Regulatory Guide 1.60.
The expected maximum ground seismic acceleration values for the plant are based upon the plant site geologic investi gations and seismologic recommendations.
The vertical design response spectra values are 2/3 those of the horizontal design response spectra for frequencies less than 0.25 cps.
For frequencies higher than 3.5,
- cps, they are the
- same, while the ratio varies between 2/3 and 1 for frequencies between 0.25 and 3.5 cps.
For frequencies higher than 33 cps, the design response spectra follows the maximum ground acceleration line.
This is
'.a.accordance with the requirement of USi<RC Regulatory Guide 1.60.
The majority of the safety class structures as described in Section B are founded on rock, except the Control and Diesel Generator Buildings.
The properties of the rock are as fol-lows:
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Shear
'slave Velocity Density Poisson's ratio 5000 ft/se" 158 lb/ft 0.15 3.5.2 3.6 3.6.2 3.7 Shear thodulus (G) 254 x 106 lbs/sq ft
.(Peference:
Dames E Moore Site Evaluation Study)
Artificial Time History Two earthquakes (OBE and SSE) representing horizontal and vertical artificial time histories shall be used as an input for generating floor respense spectra.
Artificial time his-tories to be used are compatible with the requirements of USNRC Regulatory Guide. 1.60.
Critical Damping Yalues The values of structural damping used as a percentage of critical damping for safety class structures are in com-pliance with USNPC Regulatory Guide 1.61.
Floor response spectra are generated at each preselected mass point, in each of the three orthogonal directions for damping values l...
2%
and 4% for OBE and 2%, 3/, 4/
and 7% for SSE.
Soil Structure Interaction 3.7.1 Soil Spring Data The soil data used to determine the soil structure interac-tion spring stiffnesses and damping values are derived from the available soil data for the plant.
(Reference Dames 8
Yioore Supplemental Foundation Study)
Upper and lower bound values are provided for the soil spring stiffness values.
The average values are used for the analysis.
The soil stif-fness properties are input as a sei.of six discrete springs in each model (one for each general degree of freedom),
not supported on rock.
The springs are.connected to a single nodal poi nt on each of the models.
'This nodal poi nt is located horizontally at the centroid of the plan views of the base mat outlines.
The other ends of the springs are consid-ered as being fixed.
The soil springs represent a pure stif-fness unit, and do not require or represent any length.. The structures which are supported on rock are considered f;xed because the embedment has only negligible effect on the dyna-mic response.
No soil structure interaction is considered.
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3.7.2 3..8 3.8.1 3.8.2 3.9 Soil Damping Damping in this analysis is represented in the form of str uc-tural damping in accordance with USllRC Regulatory Guide i.61 and soil radi ati onal damping based on elastic hal space theory.
Procedure Used for Model.;ng The basic te hnique used for modeling is to represent the dynamic syst m by a system of lumped masses located at'he elevation of mass concentration, such as loor slabs.
For structures such as tne containment
- shell, havi ng conti nuous
'ass distri bution, a sufficient number of mass poi nts are chosen so that tne vibration mode of interest can be ade-quately defined.
Soil is represented by springs.
The Containment Building model is an independent structure,-
while th model'for the balance of plant buildings consists of an assemblage'f beam elements havi ng structural beam properties, interconnected at nodal points.
C Methods Used to Account for Torsional Effects A structure with an eccentricity between the mass center and the center of rigidity g.eater than five percent of the dimension of the structure normal to the input direction, is considered to have pronounced torsional modes.
For a struc-ture with pronounced torsiona1
- modes, or in other words, where the horizontal responses are significantly coupled, a
three dimensional mod 1 is used in the analysis to calculate the actual torsional responses.
In the model, walls are simulated as single members and floors are treated as a rigid diaphragms.
Mass centers and centers of rigidity are calcu-lated and considered in the geometry of the model.
The acceleration time history is input at the support of the model to calculate ihe ac.ual torsional effects.
For a
symmetrical building, a
two dimensional model will give the same result as a three dimensional
- model, because the com-ponents of the mode shapes are uncoupled.
Responses due to horizontal excitations and vertical excitation are calculated separately but the effects are additive in determining forces throughout the structure.
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a
4.0 Piping Systems Anal s'is 4.1 4.2 4.3 4.3.1 4.3.2 4.3.2.1 Presented in this section are the analytical methods criteria and stress criteria which will be us d in the piping system seismic upgrading program.
The seismic analysis methods will employ dynamic sys'.em analysis techniques, and where applica-ble, equivalent dynamic static analysis.
..]he stress criteria will conform to pip.ng code USAS 831. 1 which was the
.licensing base for the Ginna Station.
The criteria described in this section will apply to the piping syst ms defined in Section 1.2.2.
Background
In the years since the Ginna Station was designed, seismic analysis techniques hive become more rigorous and the ASNE Boiler and Pressure Vessel Code Section III, Nuclear Power Plant Components, has been published, reflecting changes in
- analysis, design, and quality control techniques.
The purpose of these criteria is to establish requirements for per orming the upgrading seismic analyses of the above piping systems using current technology.
The original design criteria used for the seismic design Category I piping and supports of the Ginna Station are defined by the following codes.
Seismic design Category I piping USAS 831.1 Code 4.3.2.2 4.3.3 Supports AISC Specification for Design, Fabrication, and Erection of Structure Steel for Buildings, 6th Edition The piping code, USAS 831.1, was updated on June 30, 1973 revising tne piping stress analysis formulas and stress intensification factors.
The primary stress equations are similar to those given in the ASHE Section III code of that time.
The stress intensification factors given in this ver-sion of the code were expanded to include more fittings than in previous edition, as well as higher values for certain existing fittings.
In the piping system seismic upgrading
- program, the ANSI 831.1
- Code, Summer 1973 Addenda, will be used primarily, with tne following exception.
The piping criteria will not consider the 831.1 Summer 1973 Addenda stress intensification factors -or butt and socket welds, since they are constrictively higher than the original design basis 1967 831. 1 stress intensiFication factors.
Use or this version of the Code will therefore maintain the philosophy of 831.1, and reflect the concepts of AS!!E Section III.
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- 4. 3.4 4.4 The support criteria defined by the AISC Code was used as the basis for formulating 1974 Subsec:ion l)F of ASllE Sec ion III, which is concerned with the structural criteria for co,,ponent supports.
- herefore, Subsection,"lF of ASIDE Sect',on III will be used to evaluate the structural adequacy of the piping supports.
Loads 4.4.1 The pip',ng systems will be analyzed for the following loading conditions:
4.4.1.1 4.4 '.2 4.4.1.3 4.4.2 Deadweigh= Condition - deadweight
.and design pressure.
Design Condition operational basis earthquake (OBE) com-bined with maximum operating thermal, deadweight, OBE dis-placements, and design oressure.
SSE Seismic Condition safe shutdown earthquake (SSE) com-bined with operai'.ng pressure and deadweight and normal operating thermal.
In the seismic upgrading program the loss-of-coolant accident will not be considered.
4.4. 3 4,4.4 The seismic pipe stresses will be determined using seismic loads generated considering the piping systems to have the following damping values.
Small diameter piping systems, diameter less than 12-inch, For OBE the damping value is 1%.
For SSE the damping value is 2%.
Large diameter piping systems, diameter equal to or greater than 12 inches, For OBE the damping value is 2%.
For SSE the damping value is 4%.
An envelope of seismic response spectra at support points on the piping model will be employed in the analyses to generate the OBE and SSE seismic loads.
4.5.1 Stress Criteria Piping The loading combinations and associated stress limits to be used for the piping systems which are part of the seismic upgrading programs a~ e given in Table V-1.
As stated in Section 4.4.2, pipe rupture loads are not considered; as
- such, the stress limits used for"the SSE condition do not Criteria Document ERR 2512 Page 22 Revision 0
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4.5.2 4.5.2.1 correspond to the faulted condition, as they could he for the SSE evaluation, bu-'o the emergency condition stress limits.
Tnis is cons'.stent with the FSAR and is conserva-tive.
The piping str sses are to be calculated using tho formulas giv. n in AltSI 831.1-1973, 1973 Sur m r Addenda.
Thermal stresses ar to be evaluated per ANSI 831.1-1973, Summer 1973 Addenda requirements.
Equipment Hozzles (excluding valve nozzles)
Primary Equipment 4.5.2.2 (2)
(3)
The maximum loads that the main feedwater p',pi ng and steam line piping are permitted.to transmit to the steam generator nozzles are given in Table V-II.
The allowable loads fo'r the seal injection and component cooling system nozzles on the reactor coolant pump and motor are listed in Table V-III.
Auxiliary Equipment For Class 1
and 2 auxiliary equipment
- nozzles, i.e.,
- tanks, pumps, and heat exchangers, the reactions imposed by the attacned piping shall be compared with the following:
P
= Axial force
< 0.01 x Sy x A Hb
= Bending moment
< 0.1 x Sy t'iT = Torsional moment
< 2(0.1 x Sy x Z)
(4) where VShear force
< 0.01 x Sy x A Sy Yield stress of pipe at operating temperature as given in ASYiE Sect>on III (psi );
tiaterial cross-sectional area of pipe (in2)
Section modulus of pipe Axial force
= fx tabb ti
+ tiZ t'iT
= Torsional moment
= tiX V
= Shear force
=
f
+ fZ Criteria Oocument EWR 2512 Page 23 Revision 0
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4.5.3 These allowables are to be used as guides by the piping analyst.
For equipment of this vintage, some qualification to,the actual calculated load may-be required.
Valves The applicable valve nozzle load acceptance criteria depends on whether the valve is classified as being active or i nac-tive.
4.5.3.1 An active valve'is defined as one that is required to operate so that ihe plant can 'go from normal full poiIer operati on to cold shutdown ollowing an earthquake.
A valve must perform some mechanical motion in accomplishing its design function in order to qualify for this designation.
For active valves, the pipe loads at the pipe/valve interface shall be limited to current Hesti nghouse acceptability limits.
Valve T e
Swing Check Safety 0 erabilit End nozzle Load Limits.
~max
< Sy; with
~bending
< 0.75 Sy otorsion
< 0.5 Sy a.
Closed position - loads shown on applicable vendor drawings.
b.
Open position - oax
< 0 75 Sy
~max Other than Swing Check orna
< 3/4 Sy; and Safety (includes
.6th obending
<- 0.5 Sy diaphragm valves) atorsion
< 0.5 Sy
= maximum principal stress (using pipe properties) in the attached piping-at the pipe-=o-valve interface due to combined axial,
- shear, torsional and bending moment loads includinq pressure effects for speci-fied loading conditions.
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obending
= llaximum fiber stress in <he.attacheJ pioing at
".ne pipe-to-valve interface (using sec-.ion noaulus o-,
pine) due to resultant bending moment loads for specified loading conditions.
otorsion
= Maximum fiber stress in the attached piping at the pipe-to-valve interface (using pipe properties) due to torsional moment loads for s'pecified loading conditions.
Sy 4.5.3.2 4.5.3.3
= Yield stress (in tension) at design temperatures of material ASNE SA-376, Type 3i6, for stainless steel valves and ASHE SA-106, Grade B for carbon steel valves for operability end nozzle load limits.
4 All valves that are not classified as active are considered inactive and the structural integrity of the valve must be assured.
Since valves are stronger than the attached pipe (without a histpry of gross failure of their pressure boundaries),
as long as the stresses of the piping attached to the valve remain within the limits stated in this docu-
- ment, tne valve integrity is assured.
In addition to the above requi rements, the seismic accelera-tions of both active and inactive valves shall'be calcu-lated.
If accelerations are less than 2.1g in the vertical direction and 2.lg in each of two perpendicular horizontal directions for SSE, then the valve is satisfactory.
If accelerations are greater than or equal to 2.lg, case-by-case analysis will decide acceptability or unacceptability.
The OBE accel erati ons shall be kept to one-half of the SSE accel-eration allowables.
4.5.3.4 4.6 4.6.1 The piping analyst is responsible for checking both the noz-zle loads and seismic accelerations outlined above.
Any suggestions on supporting the valve operator in o~ der to reduce seismic accelerations or pipe overstress problems will be evaluated on a case-by-case
- basis, as required.
Analysis Analytical Procedure 4.6.1.2 The defined auxiliary piping/support systems wi 11 be evalu-ated incorporating three-dimensional static and dynamic models which include the effects of the supports, valves and equipment.
The static and dynamic analysis employs the dis-placement
- method, lumped par ameters, stiffness matrix formu-lation and assumes that all components and piping behave in a
linear elastic manner.
The response spectra model analysis technique will be used to analyze piping.
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4.6.1.3 The se ismic analyses Nl 1 I
be based on the OBE and SSE being initiated while the plant is at the normal full power condi-tion.
4.6.1.4 4.6.1.5 4.6.1.6 The oercentage of the critical damping value to be used in the analysis o-,
thh pip'.ng system is given in Section 4.4.2.
The ana'.ysis procedures for damping are given below.
For a coupled system with different damping and different structural
- elements, such as would be the case in analysis with coupling between concrete structures and welded steel components, the methcd to be used for damping is either to:
(a) use the damping which results. in the highest
- load, (b)
'inspect the mode shapes to determine which modes correspond with a particular structural
- element, and then use the damping associated with that element having predominant-motion, or (c) use composite modal
'damping value =or each mode which is calculated by weighting the damping in each subsys-tem by the amount of strain energy in each subsystem.
For piping systems interconnected between floors of a struc-ture and/or building, the envelope of the respective floor response spectra shall be used in the seismic analysis.
- 4. 6.1. 7 4.6.1.8 4.6.1.9 The piping will be analyzed for the simultaneous occurrence of two horizontal components and one vertical earthquake input component.
The response spectra associ ated with each earthquake compo-nent shall be applied in each directi on separately.
The combined modal response for each item of interest (e.g.,
- force, disolacement,,
stress) resulting from each component analysis will be combined by the square-root-of-the-sum-of-the-squares method.
The combination of modal responses will be in accordance with Regulatory Guide 1.92 or, as an acceptable alternative, in accordance with subsection 3.7.3.4 of 'Res.inghouse RESAR-41 as described below.
The total seismic response for each analysis shall be obtained by combining tie individual modal response utilizing +he square-root-of-th
-sum-of-the-squares method.
4.6.1.10 For systems having modes with closely spac>d frequencies, the above method shall be modified to include "'.e possible effect of these modes.
The groups of closely spaced modes shall be chosen such that the difference between th frequencies of the first mode and the last mode in. the group does not exceed 10 percent of the lower frequency.
Combired total response for systems which have such closely spaced modal frequencies will be obtained in accordance with Regula"'ory Guide 1.92 or, as an acceptable alternative, the followin,"'ethod.
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F requency groups are formed starting from the lowest fre-quencv and working tcward successively higher t requencies.
No frequency should be included in more than one group.
The resultant unidirectional response for systems, having such closely spaced modal frequencies shall be obtained by the square-root-of (a) the sum-of-the-squares of -all modes, and (b) tho product of the responses of the modes in various roups of closely sp:ced modes and associ ated coup'iing
~ actors, c.
The mathematical expression for tnis method (with R as the item of interest) is:
H R.
1 where:
S N-1 N
R..+2 g
Z Z
RKR. <<, for:g ~K j=1 K=t1. K=K+1 J
R;
= resultant unidirectional response for direction i; i=1,2,3 I
Rij
= absolute value of response of direction i, mode j N
= total number of modes considered S
= number of groups of closely spaced modes
~'ij
= lowest moda'I number associated with group j of, closely spaced modes "j
= highest modal number associated with group j of closely spaced modes eQ,
= coupling factor with and Criteri a Document GfR 2512 Page 27 Revision 0
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fraction of critical damping in closely soaced mode K
duration of the earthquake (seconds)
Total response, RT is 3
R
~
R 2
T
~ i i
The analyses performed for piping and supports will not include stresses resul ting from SSE induced differential motion.
These stresses are secondary in nature, based on AStlE Code rules for piping (ll8-3652, HB-3656, F-1360) and component supports (NF-3231).
The safe shutdown earthquake, being a very low probability single occur".ence
- event, is treated as a faulted condition.
Therefore, consistent with present AS (E philosophy, the secondary stresses associated with the SSE i nduced di7ferential motion will not be evalu-ated when performing seismic analysis per the response spec-trum mothod.
The basic characteristic of these stresses is that they are self-limiting, Local yielding and minor dis-tortions will sat-isfy the initial conditions that caused the stress to occur.
OBE induced differential motion is to be considered.
4.6.1.12 Tne analysis of equipment subjected to seismic loading involves several basic steps, the first of which is the establishment of the intensity of the seismic loading.
Con-sidering that the seismic input originates at the point of.
- support, the resoonse of'he piping and its associ ated sup-
- ports, based upon the'mass and stiffness characteristics of the system, will determine the seismic accelerations which the equipment must withstand.
Three ranges of equipment/sup-port behavior that affect the magnitude of the seismic accel-eration are possible:
l.
If the equipment is rigid relative to the structure, the maximum acceleration oi the equipment mass approaches that of the structure at the point of equipment support.
The equipment acceleration value in this case Criteria Document EWR 2512 P age 28
~ )
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corresponds to the low period region of the floor response spectra.
2.
If the equipment is very flexible relativ to the struc-
- ture, the internal distort~on of.the structure is unim-portant and the equipment behaves as though supported on the ground.
'3.
If the periods of the equipment and supporting structure are nearly equal, resonance occurs and must be taken into account.
4.6.1.13 4.6.1.14 4.6.1.15 Also, equipment/support systems havi ng natural frequencies greater than 33 Hz are considered rigid.
The natural fre-quencies will be determined, based on the as-built condition and appropriately considered in the analysis.
The static load equivalent or static analysis method involves the multiplication of the total wei oht of th equipment or component member by the 'specified seismic acceleration coef-ficient.
The magnitude of the seismic acceleration coef-ficient is established on the basis of ihe expected dynamic response characteristics of the component.
Components which can be adequately characterized as single-degree-of-freedom systems or are rigid are considered to have a modal partici-pation factor of one.
Seismic acceleration coefficients for multi-degree-of-reedom systems which may be in the resonance region of the amplified response spectra curves are increased by 50 percent to account conservatively for the increased modal participation.
For small piping (2" and smaller) as an option to dynamic
- analysis, either the equivalent dynamic or static rigid range approach can be used.
If the small piping system has low operating temperature, then the pipe lines can be analyzed usi ng equivalent static loads based on spacing t able tech-niques.
The static rigid range approach is used for rigid piping systems which are defined as having natural frequen-cies greater than 33 Hz.
In this case, th~ piping system is analyzed with sta'ic equivalent loads corr=.sponding to accel-eration in the rigid range of the applicab/e response spec-trum curves.
Both horizontal and vertical static equivalent loads are applied to rigid piping systems.
The response of the piping system for two orthogonal horizontal directions and one vertical direction are combined on a square-root-of-the-sum-of-squares basi s.
For any piping that can be shown to be rigid (lowest natural frequency greater than 33 Hz),
as an option to performing a
dynamic analysis, the static rigid range a~proach may be used.
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4,6.1.16 The following branch line analytical procedure and criteria wi 11 be used:
1.
The branch line is not included in the ran model if its section modulus is 15K or-less of the run section modulus.
2.
3.
For, branch lines which have section moduli greater than 15% of the run section modulus, the branch line will be modeled initially for a distance of 15'0".
If it is later determi ned by the piping analyst that additional modeling information is required, it will be provided and included within. the analysis model.
In the run analysis where the branch line has not been
- included, the branch allowable bending moments will be included.
Us'ing 831.1 Summer 1973 Addenda, Formula 12, the branch allowable moment can be expressed as follows:
8 PDo IIPR
= Branch Allowable ~1omena
= ~PPKSh, (Ocn
)
tlote: This cannot be more than 15~ of the run allowable stress (ksh)
The revised formula becomes:
+.
ta+
.(ks -())
<ks PDo 0.75i 8
PDo 4tn ZR A
0 75i h
4tn R
4.6.1.17 4.
For branch lines which are not included in the model, supports within 10 feet of the run should be noted since a support near the run pipe could effect the branch line flexibi 1 ity.
Piping which extends beyond the scope of the seismic upgrading program effort will be included within the analysis only insofar as it affects fluid lines within scope.
In
- general, piping should oe modeled for a distance which covers a minimum of one rigid support in each of the three global directions.
Case by case judgements will be made when the above is insufficient or infeasible.
4.6.2 Piping Systems Models Criteria Document fWR 2512 Page 30 Revision 0
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4.6.2.1 Piping )1odeling T chniques for Static Analysis The piping system models are to be represented by an ordered set of data which numerically describes the physical system.
The spatial geomet'ric d scription'f the pipihg mod 1 is based uoon
.he as-built isometric piping.drawings and equip-ment drawings.
Node poi nt coordinates and incremental
~ lengths of the members are determined from these drawings.
Node point coordinates are input on network cards.
In r men-tal member lengths are input on element cards.
The geometri-'al properties along with th modulus of elasticity, E, the coef icient of thermal expansion,;.u, the average tempera-ture change from ambient,.hT, and the weight per unit
- length, w, are specified for each element.
The supports are represented by stif ness matrices which define restraint, characteristics of th.'upports.
A network model is to be made up of a number of sections, each having an overall transfer relationship formed from its group of elements.
The linear elastic properties of the section are to be used to define the characteristic stiffness matrix for the section.
Using the transfer relationship for a section, the loads required to suppress all deflections at the ends of the section arising from the thermal and boundary forces for the section are obtained.
These loads are incor-porated into the overall load vector, After all the secti ons have been defined in this manner, the overall stiffness matrix K an'd associated load vector, to suppress the deflection of all the network points, is to be determined.
By inverting the stiffness matrix, the flexibil-ity matrix is to be determined.
The f'lexibility matrix is multiplied by the negative of the load -vector to determine the network point deflections due to the thermal and boundary force effects.
Using the general transfer relationship, the deflections and internal forces are then determi ned at all node points in the system.
The support loads
[ F ] are also computed by multiplying the stiffness matrix K by the dis-placement vector jB ] at the support point.
The models used in the static analyses are to be modified for use in the dynamic analyses by including the mass character-istics of the piping and equipment.
The 1umping of the distributed mass of the piping systems is to be accomplished by locating the total mass at points in the system which will appropriately represent the response of the distributed system.
Effects of the equipment motion will be obtained by modeling the mass and the stiffness character-istics of the equipment in the overall system model when required.
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4.6.2.2 The suoports are aga'n represented by stiffness matrices in the system model for the dynamic analysis.
Hydraulic shock suppressors which resist rapid motions are to be considered in the analysis.
From the mathematical description of the system, the overall stiffness matrix [Y,] is to be developed from the individual element stiffness mat, ices using the transfer matrix L KRj associated Niih mass degrees-or--,
reedom only.
From ihe mass matrix and the reduced stiffness matrix, the natural fre-quencies and the normal'modes are to be determined.
The effect of eccentric
- masses, such as valves and extended structures, are considered in the seismic piping analyses.
These eccentric masses are modeled in the system analysis, and the torsional effects caused by them are evaluated and included in the total system response.
The total respon'se must meet the limits of the criteria applicable to the safety class of the piping.
Valve Model 4.6.2.3 4.6.2.4 Valves will be included in the piping system model.
The model employed should reflect non-rigid behavior as well as rigid behavior.
For rigid valves, the model used should consist of a rigid beam element from ihe center of the run pipe to the center of gravity (cg) of the valve.
The mass of the valve should be located at the valve cg.
For non-rigid
- valves, the model should have two masses.
Equipment Model Where the stiffness and mass of the equipment attached to the piping will influence the piping system being analyzed, the piping model must include the equipment effect.
This is to be accomplished by including in the piping model a model of the equipment to the detail necessary.
Interaction Effects Inter action of other piping systems are to be considered when their response will effect the response of ihe line being analyzed.
The reactor coolant loop, RCL, should be included in the piping system model to the extent of detail required.
If the lines being analyzed are relatively small diameter and/or low temperature the RCL need not be i,ncluded in the model.
This is because these lines are so flexible that the RCL deflection will noi induce significant stresses in the lines, or that the RCL response characteris".ics will not
, cause exciting forces different from those associated with the inner containment building.
Criteria Document EWR 2512 Page 32 Revision 0
Date 4/2/80
4.6.3 4.6.3.1 4.6.3.2 Where branch piping is attached to the piping being analyzed, its ef>ect on the piping of inte. est is accounted for by modeling in accordance with the criteria of 4.6.1.16.
Piping Supports The stiffness of the supports shall be considered in the piping system models.
Tne local subsystem stiffness of all
.piping and equipment supports shall be determined considering the pipe or equipment supports along with the structural steel and/or concrete e feet.
The localized subsystem stiff-n ss of all pipino and equipment supported by reinforced concrete m mbers (including concrete pedestals) shall be considered when significaqt.
The stiffness shall be based on the face of concrete interface.
Rigid supports shall be modeled in accordance with the fol-lowing criteria.
Nominal Pipe Siz Kmin Ri id (lb/in)
Yrmin Rigid (in/lb/rad)
< 2 inch
$-4 inch 6
1 neil 1 x 105 5 x 105 1 x 106 1 x 107 5 x 107 1 x 108 4.6.3.3 Use of the above guidelines eliminates excessive support stiffness calculation effort, while yielding satisfactory support displacement results (i.e., thermal deflections
.02 inch, rotations
<.0002 radians).
"Common pipe supports" refer to those supports to which two or more pipes are attached in such a way th'=-t signi,icant coupling occurs between the pipes.
When al~ attached pipes are the same size and the distances to -adjacent supports are similar, the local subsystem stiffness shal) oe based on the deflections resulting from an equal load ac~ing at all sup-port points.
When different size pipes are attached, or if the distances to adjacent supports are not ~imilar, a stiff-ness matrix relating the orces and displace!!'ents at the points of attach'ment to one another shall be provided to the piping analyst for his use in uncoupling the piping systems.
Criteria Document EWR 2512 Page 33 R'evision 0
2'ate 4/2/80
4.6.3.4 Hydraulic seismic sut.'oorts (snubbers) generally lock up at an excltatlon freoiJency Gf approximately 1 Hz, 'v'lih a piping di placement cf.05 inches.
Yechanical snubbers activate in a freq ency range of 1 to 6 Hz with a similar piping displacereni of.05 'nches.
As piping system frequenciies seldom exist below this range, 'seismic supports wi 11 be modeled as active during all seismic events.
4.6.3.
5 Supports will be considered active statically in any given direction provided the support gap in hat direction does not exceed
.125 inches.
This
.125 inch tolerance is essentially construe.ion
- variance, wnich does not alter the designed function of the support.
Supports with gaps greater than
.125 inch will be incorporated as follows.
System analysis will first assume that the support is not active; piping displacemients resulting from this run will then be used to ascertain the validity of this assumption.
If incorrect, reanalysis will, incorporate an active support statically.
Criteria Document EHR 2512 Page 34 Revision 0
Date 4/2/80
5.0 Piping Supports Analysis 5.1 Presented in this section is the stress criteria which wi 11 be used to valua'e the piping system supports associated wi th the seismic upgrading program.
Loads
.The p-.:ping system component supports wil'l be evaluated to the following combinations of resultant piping system imposed loads and support inerti a effects:
1.
Horma1 Condi tion:
Deadweight and maximum operating thermal 2.
Desi gn Condi tion:
Deadweight, maximum operating thermal and operational basis earthquake.
5.2 3.
SSE Condition:
Stress Criteria Deadweight, normal operating thermal and safe shutdown earthquake.
The piping system component supports will be designed and evaluated for the loading conditi ons specified in Section
- 5. 1.
The loading combinations and associated stress limits which are part of the seismic upgrading program are given in Table YI-1.
The stress limits given are corsistent with the FSAR Appendix 4A commitments.
The allowable stress criteria is in accordance with Subsection HF of the ASt~iE Section III
- Code, 1974.
i'tote that faulted condition stress allowables from Appendix F of the ASblE Section III Code and US NRC Regu-latory Guide 1.124 will be used to analyze ihe supports for the SSE condition.
The variance in allowable criteria between the piping and supports will not casse over or under-designs to occur, as the satisfaction of the OBE condi-tion to the working stress limits will in alll cases be most stringent.
The ccnlponent support embedments will be evalu-ated using current analytical techniques in accordance with Hilti Technical Information.
The expansion anchorages shall meet the requirements set forth in t)RC IE Balletin Ho. 79.02.
Cri teria Document EMR 2512 Page Revision 0
Bate 4/2/80
For ancho'rs which separate Seismic Category I piping systems from non-seismic Category I piping, the loads from the Seismic Category I side will be doubled.
The effects of friction on supports will be considered
=or pipes having thermal movements..
The value of p will be 0.75.
Criteria Document El<R 2512 Page
'36 Revision 0
Date 4/2/80
6.0
- Codes, Standards and Regulator Requirements 6.1 6.2 6.3 The seismic upgrading program will encompass piping systems which are Seismic Category I, 2 1/2" and larger, within the following structures; containment, interior structure, tur-bine, auxiliary, intermediate, cont. ol, and diesel generator buildings.
Branch line inclusions and class break overlaps are exceptions to the above.
Seismic Category I systems are analyzed to the ANSI-B31.1 Summer 1973 Code.
Seismic Category I systems do not include non-nuclear safety (VHS) systems.
The codes and standards to which the seismic upgrading pro-gram systems will comply are outlined in Sections 4.3.2 through 4.3.4.
Criteria Document E'l]R 2512 Page Revision 0
Date 4/2/SO
7.0 S
i 0." ~iC The design and operating condi ions to which the piping systems will be analyzed are defined within the RGE Operating and Design Conditions Docu-..ents.
System thermal analyses evaluate the normal 100.'ower condition, as well as other abnormal operating transioni conditions.
The most severe upset conditions will satisfy equation 48 of Table Y-l, Loading Combinations and Stress Limits Table for Piping.
Seismic analyses will incorporate the GAi developed response spectra for both the op rational basis and safe shutdown earthquake cases.
Spectra will be derived from buildings and elevations applicable to the individual analysis lines.
Criteria Document ERR 2512 Page 38 Revision 0
Date 4/2/SO
J
APPE!lD I X 24.0 25;0 26.0 Tables Attachment 1 to Scope Document Revision Status Sheet Cl itet 1 a Document EMR 2512 Page 3g Pevision 0
Date O /02/So 3963A
Le, TABLE V-1 LOAOOlG CON IibATIO<S At')0 STRESS LIMITS FOR P IP IHG g
C Stress Limits l.
Dead:hei ght:
Design Pressure e
+ Deadriei ght m h Sh 2.
OBE Seismic:
Design Pressure
+ Deadweight P
< 1.2 Sh
+ Design Earthquake Loads
{OBE)
PL +
PB
< 1.2 Sh 3.
SSE:
Operating Pressure
+ Deadweight P
< 1.8 Sh
+ Maximum-Potential Earthqua'e PL +
PB
< 1.8 Sh Loads
.(SSE)
+ Hormal Operating Thermal 4.
Therm al:
A.
Maximum Oper ating Thermal
+
Design Pressure
+ Deadh)eight PL +
PB
< (Sh
+ SA)
Where PL PB SA Sh
+ Maximum Operating Thermal
+
OBE Displ acements prima y general methbrane stress; or stress intensity primary local membrane stress; or stress intensity primary bending stress; or stress intensity all ohiabl e stress from USAS B31.1 Code for pressure Pl Pln g thermal expansion stress frcm USAS B31. 1 code for pressure pi ping C ri ter i a Doc un en t EWR 2512 Page 4O Revision 0
Date 4/2/BO
1 I
ALLOI (qg~ t w ~ i a]
~ i,QP LIO ~ ll ~
I 0/05 Cond':tion FEEDMATER HOZZLE I
Fz Mx My Thermal Pressure We lght S~lsml c 08""
Seismic DBE 15
+221 5
150 200 40 0
15 150 200 40 2000 0
0 5
250 150 1500 200 2000 3000 3000 0.
0 500 500 2000 2CCO 3000 3000 STEAM NOZZLE Condition Thermal
', Pressure Weight Seismic 08E Seismic OBE Hotes:
100
+692 20 150 200
'y 50 0
10 150 200 Mx 50 3000 0
10 50 150 5000 200 7500 My 5000 0
500 5000 7500 Mz 5000 0
750 5000 7500 1)
-A11 loads are
+ unless indicated 2)
Units ar k'.ps and in-Hips.
3)
Coordinate sys em.
R by RHP)
(in direction o~
Rf nozzle) x-y pl a ne i s ve rt~ ca l Fee&:t,er Hozle
- Stem Nozzl e Cr iter i a Oocumen t EuR 2512 Pag Re>ision 0
D'-'- ~2
TABLE V-III REACTOR CGOLr" NT PL'.'P Al,'XIL:ARY N022L= lJf'BRE'A LCPOS Nozzle Condition/Load F
( lbs)
F
( lbs)
F M
( lbs)
( in-lbs)
'y z
th
( in-lbs)
( in-lbs )
Seal Injection Therma 1
Deadweight Seismic OBE Seismic SSE 350 10 250 800 100
=- -80 op 250 3200 350 300
.-3500 10 300 225 1600 2800 250 4500 15000 2000 400 2000 4000 No.
1 Seal Bypass No.
1 Seal Leakoff No.
2 Seal
- Leakof, No.
3 Seal Injection No.
3 Seal Leakoff Therma 1
Barrier CCM In 5 Out Thermal Deadweight
'eismic PBE Seismic SSE Thermal Deadweight Seismic OBE Seismic SSE Thermal Deadrreight Seismic OBE Seismic SSE Thermal Deadweight Seismic QBE Seismic SSF Thermal Deadweight Seismic OBE Seismic SSE Therma 1
Deadweight Seismic OBE Seismic SSE
'5 5
50 160 400 1-
~
500 800 75 5
50 160 90 15 90 180 ap 15 90 180 75 20 100 200 70
-25
.50 170 200
-80 400 500 100
-25 100 170 45 35 150 300 45 35 150 300 200
-75 250 700 40 1
45 170 300 5
500 600 100 5
100 170 45 10 150 300 45'0 150 300 150 1
100 200 300 75 900 1650 2000 300 1000 2000 300 75 900 1650 290 90 480 960 290 90 480 960 3200 5
1000 4500 315 50
.1200 2550 2000 250 5000 8000 350 75 1500 2500 "290 45 560 1120 290 45 560 1120 1300 5
1200 3000 1525 350 900 2000 2000 4PQ 2000 3500 1600 400 1200 2000 180 180 480 960 180 180 480 960 2500 150 1200 3600 Criteria Dcc"ment E~rJR 2512 Page 42 4 / 02/80 Date Revi s'.,on 3963A
Nozz'je FF F
Cond ition/Lead
( lbs)
( lbs)
( lbs)
H M
( in-lbs)
( in-lbs)
M
( in-lbs)
-Upper Bearing Oil Ccoler E
Air Cooler CC'I In E
Out Lower Bearing Oil Cooler CCW In I)
Out Notes:
Ther al Dead'ue i h
') sirllc 0
'eismic SSE Thermia 1
De dueignt Seism c
OBE Seismic SS=
100 100 5
-80 100 300 200 600 95 340 10 '35 90 90 90 90 100i 300 600
. 305 10 90 90 300 100 500 1000 470 100 290 290 300 50 600 1200 480 125 290 290 200 200 500 1000 525 125 180 180 2) 3)
4) 5)
Yalues at +/- unless otherwise specified.
Loads cn the No.
3
- s. al connections apply only if a No.
3 "Double Dam" seal is supplied.
Loads cn pump nozzles aro to be applied at the nozzle to shell Juncture.
Loads on motor nozz'Ies are to be applied at the flange end.
Coordinate System:
Z - by Right-Hand-Rule Criteria Document ERR 2512 Page Revision Date 4/02/80 3963A
TABLE VI-1 LOADING COMBINATIONS At/0 STRESS LIllITS FOR SUPPORTS ON PIPING SYST'-iiS Loadina Combination Stress Limits Upset:
Faulted:
Decor D.+ F+ T+
E D + E'r 0 +
F + T
+
E' Normal:
D or 0 +
F + T
< Working Stress(
)
< Working Stress(
< Faulted Stress(
Deadweight and thermal are combined algebraicly D
= Deadweight T
= Maximum operating thermal condition for system F
= Friction Load (3)
E
= OBE
( Intertia load
+ seismic differential support movement)
E' SSE
( Inertia load + seismic differential support movement)
T
= Thermal - Operating Temperature 0
(1)
Working stress allowable per Appendix XVII of ASHE III.
(2)
Faulted stress allowable per Appendix XVII, Subsection NF, and Appendix F of ASHE III and USNRC Regulatory Guide 1. 124.
Safety Class 1 supports iiill be evaluated and designed in accordance with position 8 of Regulatory Guide 1.124.
(3)
Whenever the thermal movement of the pipe causes the pipe to slide over any member of a support,, friction shall be considered.
The applied friction force applied to the support is the lesser of p W
or the force generated by displacing the support an amount equal to the pipe displacement.
p
=
.75 W
=
Normal load (excluding seismic) applied to the member on which the pipe slides.
Criteria Document EWR 2512 Page 44 Revision 0
Date 4/2/8O
TABLE VI-I (CONTINUED)
LOADING COl!~Ii"ATIONS AND STRESS LIHITS FOR SUPPORTS ON PIPING SYSTEtlS (4)
Expansive anchorages shall meet the requirements of NRC IE Bulletin 79-02.
Component Standard Supports (New and Existing)
For component standard supports which have certi ied load capacity data sheets (LCDS), the loads given on the LCDS shall serve as the maximum allowable load for the given loading condition.
For component standard supports which do not have certified LCDS, the catalog allo; able load at the time of manufacture will be pro-rated for the various loading conditions by the same factor used for the same component with a LCDS..
The prorated load shall serve as the maximum allowable load 'for the given.loading condition.
Supports Fabricated from Non Cata'log Items The stress limits for supports fabricated from non-catalog items shall be based on allo<<able stresses from ASHE III, ANSI or ASTi'I material standards at the time of procurement for the material used.
If the material is not known, it is assumed to be A-36 carbon steel.
Criteria Document El!R 2512 Page Revision 0
Date 4/2/80
Attachment 1
to Ginna.station Seismic Upgrading Program Scope Document ERR 2512 RC4i/NRC Meeting Minutes July 24, 1979 Revision 1
September 24, 1979 Criteria Oocument Pr/R 2512 Page Revis ion 0
Oate
< /02/80
RGE Decision "" Door de Ginna Station Seismic Anal;sis of Ca.ecorv I Piping S stems 3-Year Prooram roti tment Mav 1979 Dynamic an lysis of essential saf "ty systems to current standards
=or dynamic analysis.
Modi ications to piping as required to upgrade to new standard to extent practical.
II.
Basis for Orioinal Seismic Qualification Housner ground response spectrums
critical damping.
Equivalent Static Analysis of 2'," and large.
Cat I piping systems.
S
+
S
+
S
( 1.8 S
Seismic O'A press '
SSE Field run piping 2" and less to conservative B31.1 code spacing
'criteria for vertical and horizontal forces.
Design ver ification by dynamic analysis of 2 piping systems inside containment A RHR, 8 Main Steam.
System walkdown by seismic Westinghouse,
- GAl, RGE engineers, June 1969.
Documentation (minimal record keeping requirements of late 1960s).
III.
Challenges to Existina Seismic Analysis Maj or Modification Programs (high energy backfits outside containment 1974, Standby'uxiliary System
- 1975, Spen Fuel Pit Cooling 1977)
Corporate Decision 1974 to design and construct major modific tion to current codes and standards
- Section 3 with dynamic analysis including structural r'esponse.
Criteria Document ERR 2512 Page 47 Revision 0
Date 4 /02/80 3963A
iiRC se'.smic S-".'ev'.ew pr gr m (structures, equipment, piping) independent review or original seismic qualification using current analysis techniques.
Current Regulatory Seismic'Concerns.
IE Bulletins 79-02 Anchor Bolts 79-04 Velan Valves 79-07 Algebraic Summation 79-14 As-Built Configuration IV.
Benefits to RGE of Seismic Upgrade Analysis Upgrade Program Provides a consistent design basis seismic analysis bas line for essential Cat I piping systems
.for future evaluation during next 10 years.
Provides a level of design documentation for analysis and support design consisten with current practice and record keeping requirements; Permit a systematic aoproach to development of design and analytical data versus chaotic efforts associated with current and future bulletin concerns.
Provide seismic and input data based on cur, ent system configuration to SEP evaluators (scheduled to maximize manpower produc ivity).
Provides consistent means of evaluation for future modification requirements (i.e.
- SEP, Three i~lile Island, High Energy Inside Containment, etc. )
Upgrades olant seismic design to current industry standards.
Includes effects of soil-stricture interaction, structural amplification, higher damping values, multi-mode behavior.
Criteria Document EHR 2512 Page 48 Revision 0
Oate 4/02/80 3963A
G~l),'(A STATIOH SEISllIC UPGRADI')G PROGRAM RGE/tlRC iviEETI<'iG
- 8ETHESDA, t~D JULY 24, i979 1.
Scooe struc.ures containment and interior structure turbine, auxiliary, intermediate,
.control, diesel generator bui ldings systems seismic cat gory I, 2'," and larger, main runs critical 2" within above s.ruc.ures initial program main steam, main feedwater, auxiliary feedwater, service water, containment spray, auxiliary spray, safety injection, residual heat removal CYCS - charging,
- letdown, seal water expanded program -
reactor coolant systen, component cooling system downgrading waste disposal system exc lu s i on s screenhouse standby auxiliary feedwater building and system spent fuel pool cooling system buried piping (principa'lly service water)
LOCA and pipe break no fatigue analyses being performed pressurizer relief valve discharge piping Criteria Document ERR 2S I2 Page 49 II Date 4 / o2/."O 3963A
2.
Structural ~nalvsis method orig',nal plant desi~n utilized ground response spectra upcrading program will use floor response spectra dynamic lumped mass model 1.
coupled - contairment and intorna') structure (includes RCS) 2.
interconnect'ed buildings - turbine, auxiliary, intermediate, control, diesel generator 3.
20 for symnetrical buildings 4.
30 for structures. with significant torsional modes 5.
large equipment masses included 6.
vertical amp li ication of floors and "beams calculated separately 7.
soil structure interaction will be included in model ground response
'spectra based on 0.08g OBE, 0.20g SSc artificia1 time histories used as input for generating floor response spectra differential displacements to be calculated for OBE only criteria Reg.
Guide 1.60 - response spectra Reg.
Guide 1.61 - damping values Reg.
Guide 1.92 - combination of modal responses 3.
me thod original plant design utilized equivalent static analysis upgrading program will use response spectra modal analysis response spectra will envelope points of piping supports 30 dynamic model 1.
support stiffnesses to be included
~ 2.
eccentric
- masses, such as valve operators, included Cr iter ia Ooc umen t EMR 2612 Page 50 Revision oate 4, 02ISO 3963A
7 3.
equ ipmen-. ma"ses and sti ffnesses included where necessary 4 ~
eff ct of reac.or coolant system included =or large secondary lines 5.
ef, c. of branch lines included with main run loading conditions 1.
normal - design pressure
+ deadweight 2.
design - OBE -'esign pressure
+ deadweight 1.2 Sh 3.
SSE - SSE + operating pressure
'eadweight 1.8 Sh 4.
thermal -
OBE displacements
+ thermal pressure
+ deadweight
+ thermal
+
OBE displac,=ments Sa Sa
+ Sh criteria USAS 831. 1-1973 -'stress criteria (Surrmer 1973 Addenda)
Reg.
Guide 1.60 - damping values Reg.
Guide 1.92 or RESAR 41 - combination of modal responses criteria developed for allowable loads on equipment models,
- valves, and branch piping 4.
Support Analysis stresses due to OBE differential motion only,will be calculated
,method original plant component supports utilized manufacturers standards fabricated supports designed and fabricated to AISC Code upgrading program will analyze supports in 3 stages 1.
calculation of sti fnesses for piping analyses 2.
comparison of new loads against original 3.
redesign of existing supports and des.'gn of new supports as necessary Criteria Oocument ERR 2512 Page 5l Revision 0
Oate 4(OZIBO 904'5 h
'L l
embedments will be included in evaluating integrity of existing s uppor ts base plate flexibilitywill be included loading ccnbinations evaluated will be sane as pip',ng cri teri a ASllE III, Subsection i'iF - stress criteria (1974)
Reg.'uide 1.124 - service limits and loading combinations ACI-349, App.
8 - enbedments 5.
Nodi ficati ons existing supports repl ace load rated supports where new loads exceed existing rating replace or modify structural steel members (including base plates) and welds as required to meet stress limits replace embedments where necessary to meet new loads and safety factors s tr uct ure s 6.
Out put local modification/reinforcement of existing structural steel and concrete where necessary for increased loads isometr i cs as-built isometrics containing all "seismic input" information dimensions, wall thickness, materials, valves, support location and type, etc.
stress reports sur'nary and detailed stress reports for piping correspond to isometrics support and nozzle loads suiiiiary reports of support analyses comparison of calcul ated values with code zl'lowables as-bu i 1 t drawi n gs pi pi ng or tho graph i c drawi ngs pipe support location and detail drawings rated support loads Criter i a Ooc unpen t
EWR 2512 Page 52 Revi sion 0
Oate 4/2/60
"26.0 R"'I!S*C'f Si'iUS Sil:":
Page Latest Rev.
Page Latest Rev.
Page Latest Rev.
Criteria Document.
EMR 2512 Page 53 Revision 0
Date 4 g2 /80 3963A
Cr~ tevg a ro sel r-c ion o. linr-'s ti}e D~ D" }c uDc ace
~ crag
- 1.0 2.0 h
Only D'ping that is consicered seismic Category I. as scent x-.
e-l by the co'0- cocec P" D's in ADDeI}Q3.X A of
.the Ginna Sta-ion Q.. Hanual Shall be
>nc uc d.
Ha'n ~uns of Dipina incluced sha 1 5e based on the fo '*ov'}g crlter~ a.
2.2 2.3
'3. 0 Hain runs o
piping l'hick are 2-%. inch and'arger and critical 2 inch piping.
Hain ruI.s l:hick Drovice the fluid flo'~ path to/or from ecuipment recuixec xo safe shl}tcovin aI}Q LocA mitigation basec on S:-P.
=-cuipment coes not include instrumen-ation.
Selec ed adQitiona"
}..a" I} rl}ns not inclu" d in 2. 2 but vhich are a Drimary part of the systems incluc d 'n th UDC ace Droc. am.
Branch lines incluced shall be based on the following crite ia.
3.1 3.2 3.3 Branch lines shall be inclu"ed in the analyses as necessary to cetermine th local exxects of th'e b anch lines on the main runs and to assure adeauate f e>:ibility exists in the branch line to prevent local overstress in the branch due to ma'n run Qisplacements.
Branch lines
~.hose section modulus is greater than 15%
of the main run section modulus sha'e incluceQ in the aralys' xor an apDropriate distance and/or number of suppo"ts.
I Branci. lines +hose sectioI. moculus is less than 15% of the main run section modulus do not, need to be explicitly includea 'n the analysis.
Lines Selected The olloving main lines are included in the Piping Se'smic Upgrade Pxocram:
1.0 Reactor Coolant System Primary Loop l}roe lope Scope Doc<}me}tAt.t. 2 EV'R 2512 })l,. 54 lwCl }5lt'Ifl 4)2)80
1.3 Pressuri".er spray lines from the cold legs to the ores url e 2.0 2.1 I:.ain Steam The 30" "=-;.==- from both end up to tne I"SIP's. ~ 'G's through the penetrations 2.2 Inlet piping up to safety ar.d relief val's. 3.0 Iiaxn .=eec "az r 3.1 4.0 The 14" lines fromi the SG's through the 'penetratior.s and up to check valves.3992 and 3993. Auxiliarv "reed~'ater The discharge )ines from the t')o motor driven pumps tl.e turb'ne criven pumps up to the main eec':ate con!')eci'i oins. anc 5.0 5.1 5.2 5.3 The concensate anG service water suction lines froimi the pumps to checl valves
- 4014, 4017, 4018 and to valves
- 4013, 4027, 4028.
'afety Injection The 10 inch SI accumulator discharge lines to the cold legs. S1'ump suction lines rom the EST "hrough 896 A&B and ~ 825 A&9 to the three pumps. The SI pump discharge lines from tl'e three p'imps to the SI accumulato - ciscnarge liries and to the tvo hot leg connectiors. 5 ' 5.5 5.6 The boric acic lines from the boric acid storage tanks to the SI pu)no section lane. The -"= inch alternate SI suction line from va ives 1816 A&B to the pump. The 10 inch low head SI suction from the R)iST to v.lve 854. 5.7 5 ~ 8 The 6 inch/8 inch heacer from the ";.':.'ST to valves 857 A, B, ar.d C. The 8 inch suction lines from contain s>)mp B to valves 850 A%D and tl.e 6 ir)ch b'anch lines to v ives 1810 A"B. Scope Docu:nent Att. 2 E4'R 253 2 Pi" 55 inc~ >>win IUte 4/2/80 i~ ~ %i
5.9 T le lo'ead s afetv in)ection lines fro.",. valves 852 Ac.B to th RCS. 6.0: Residual:-.eat R mo'al 6.1 6.2 6.3 The 10 inch suction lines rom the loop A hot leg to the two RHR pumps. From valves 850 P6B to the pumas. From valve 854 to th suc"ion header. 6.4 The two puma d'scha -ge.lines through heat exchangers and to the common 10 inch return. 6.5 6.6 The 10 inch return through penetration Pill and to the B cold leg. Ti e discharce cross-connect including va ves 709C and. D. 6.7 Tne heat exchanger by-pass line including valves 712 ASB. 6.8 The two lin s from the MR heat exchanger outlets to valves 857 AS~B and 1816B. 6.9 The <<ecircula-'ion line from the RHR return through valve 822B to the R:-~R suc i ion line. 6.10 The two lines rom the RHR return to valves 852 ARB. 7.0 7.1 7.2
7.3 Conta'nment
Spray The two suction lines f -om R'T header t;o the spray rings. The two pump d'charge lines and spray rings. The two eductor lines from the pump discharges to t:he pump suctions. 7,4 The spray additive lines from t:he tank througl 836 A&B and t:o the t"o eductors. 8.0 Chemical and Volume Control The auxiliary pr. ssuri"er sp. ay line the connect:ion at: reoenerat1ve heat: excnancer outlet 11ne to the pressur~"eg spray 13.ne. Scope Document Att. 2 lac~ I+ lt>ll E'l"R 2512 Pt.e 56'/2/80 P.ice
8.2 hQ 1Q co'n lin from i he PCS thrGuc 1 the reaenerati 'e he a i exc..ance r, "hroucn "he non rec~=nerative hea i exc: a:;"Qr, i.".rough; al:e TCV 145 io the'-volum con irol 8.3 The 4 i..ch h ade Irom ihe UCT and ih 3 inci. suction Xines 'io "h -i.ree chargina pumps. 8.4 "he th"ee charcina pump discharge lines to the acoustic filter. 8.5 The 2 a.nch chare'c lxnes from th acous inc fzlter throucn ihe regenerative heai exchar?ger to boih ihe hoi and cold leg conneciions. 8.6 . The 3 'ncn seal ~'aier heacer from the acoustic filter and the i',o 2 inch lir. s io ihe RCP seals. 8.7 The 2 inch seal i:ater re"'urn lines from the BCP seals and ii. 3 inch re iurn header ihrouch ih seal vater heai exchar?cer to i¹ VCT. Includ s 3/4 inch piping throuah fla~ transmitiers
- 175, 176,
- 177, and 178.
8.8 The 4 inch line from ihe Ph ST ihrouch valves E,CV 112B and 358 to ihe charging pump suc iion header. 9.0 Steam Generator Blo'godown The tvo 2 ir.cn lines from ihe SG's inrouan the penet.ra-iions io the isolation valves. 10.0 10.1 Service 'later Svsiem The inlet piping io boih diesel ceneraiors i?1cluding the cxoss-con:-.Qctior. bet~'eel. the d'esels, he 16, 14, and 10" supply to ihe Turbine Building up to valve 4613.
- 10. 2 The ouile" pip'ng rom both diesel canerators to an anchor poini ou-'side the diesel cene aior room.
10.3 The 20 inch supply lines and header 'nside the Auxiliary Building. 10.4 The 18, 14, and 6" supply 1'?..Qs frow the 20 inch header to thQ tvo co?",.po?1ent cool i?;a \\'atQI ).".Qai Qxcha 1gQI s and the spe?it, ~ ue1 pool !'Oat Qxc.".an,er. 10.5 The no mal c'ci'arce lines Mater nea i exc?1anceI s a?1d lng T he +0 I?1c?1 a':'.i'ce Gm t1'1Q o:",Do?Lent cool xng t Q ~o'~ '"<~el oool l.eat e>'- Scope Document Att. 2 2512 p> "~ 57 lan'~?4 lOII 4/2/80
c, 10.6 The 3 inch supply lom tli S ' pu..lp 473 0$% and no'al cise..azce heade"s to and and e l:p I n7 coo" e s ln the c'ui'zlza pip> ng ~) ougn va v es 738 I '3-I anc 10.7 10.8 " 6 ar!d "4 3 ncn sl pplv.!eace s 1:;s3 ce the Enter ec . a e Building. ncluding piping through valves
- 4040, 4623, 4639,'anc
-'7"6. Ti: 10 -'nch s'apply to the Turbine Building up to valve 4614. 10.9 The 4 inch supply lines to the AFV/ p imps. 10.10 10.11 The 2-', inch and from t'.".e Cooling Coil Th 2~~ inch compar ~.. nt
- 4625, 4626, and 8 incn supply and cise>>arae lir.es to 1A,.l~r, 1C and 1D Contai.L-.beni U rltlLatzon s and Fan I'!otors.
suoQlv and'czscharae l~nes foz'he reactor coo'ers, 'nclucing p'pina through valves and. 4624.
- 10. 12
- 10. 13 11.0 11.1 The 4 inch supz!ly to the air conditioning water chillers up to th
'solation valves 4663 anc 4733. Tne common discharae head r for the ventilation, coolers up to an anchor poir.t outsice the 1ntermediate Builcing. Component Coolinq \\ ater The 14 suction heacex'nd 10 inch suction lines to the CCN Dumps ~ 11.2 11.3 The CC"'u.,p discharge lines to the CCV'eat exchanaers. Tne 4 'nch and CCN surge tank lir.e. 11.4 11.5 The 10 and 14 inch si'pply heacers out of the CC'e) heat exchangers. The 10 and 14 inch suppLy lines to bot:h residual heat exchancers. 11.6 11.7 The 10 ana 14 inch ret:urn lines from the r sidual >>eat exchangers to the CC':,'umps suet:ion heacer. The 2 inch sup"ly and retu'n lines t:o the E'.2 pu:.!>p coolers. 11 ~ 8 The 14 and 8 inch supply and return }>eaders selvxc ng the reactor coo'an >>u::;ps
- -
- !d react.nr supports'.
Scope Document Att. 2 lxCi l>itin E4'R 2512 58 I'.!. c 4/2/80 D.uc.
1~ 9 lg coola inch supply and return line to both reac"o" n7 pu~ip TBovors. f' 4 )(15 ) ~~+~I?.4 The 6 131. inch supply and v e'J( C ii~i~ urn li-, s for h re.ctoX sup heacers to penetrations 130 and 11.11 The 2'incn sue-lv and retu=n Qo'nn heat er.c::an~er z.ropil one ticns 124 and 12o. 1ines for the 8 'incn heacer excess let-to Denetxa-The 6, 4, and 2'onrecenera-'ve e>:changer. ~ i Jib@ l suavely and return line 'r ezcha icer and the seal '<ater heat 11.13 ~ The 2 inch supply and r tu~-n lines =or 'both containment spr ay and bo "iY safety injecti on pu-;ps. Scope Docu:-.ent Att. 2 7i.'4 ls lfiA 0 Eh"R 2512 .'Plllc 4/2/80
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