ML20154H103
| ML20154H103 | |
| Person / Time | |
|---|---|
| Site: | Calvert Cliffs, 05000319  |
| Issue date: | 05/18/1988 |
| From: | Lippold W BALTIMORE GAS & ELECTRIC CO. |
| To: | NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM) |
| References | |
| NUDOCS 8805250226 | |
| Download: ML20154H103 (8) | |
Text
s e
BALTI M OR E GAS AND ELECTRIC CHARLES CENTER. P. O. BOX 1476 ' BALTIMORE, MARYLAND 21203 W. JAMES (JPPOLD MANAosa nucle An ENo*ettmwo Stavicts DePARTutNT hiay 18,1988 U. S. Nuclear Regulatory Commission Washington, DC 20555 ATTENTION:
Document Control Desk
SUBJECT:
Calvert Cliffs Nuclear Power Plant Unit Nos.1 & 2; Docket Nos. 50-317 & 50-318 ASME Section XI Relief Valve Testinn Reauirements
REFERENCES:
(a) Letter from hir. J. R. Lemons (BG&E) to NRC Document Control Desk, dated April 6, 1988, Request for Relief from ash 1E Section XI Relief Valve Testing Requirements (b) Conference between hir.
W.
J.
Lippold (BG&E) and staff and hir. R. A. Capra (NRC) and staff, on hiay 2,1988, same subject Gentlemen:
In Reference (a) we requested relief from certain requirements in the ash 1E Boiler and Pressure Vessel Code Section XI,1983 Edition with Addendum through Summer 1983. As a result, a meeting (Reference b) was held to address specific concerns regarding our request. This letter is in response to that meeting and supplements Reference (a).
Enclosure (1) provides information you requested in Reference (b) for the Unit I and Unit 2 IST relief valves. Information on the code safeties is not included. We will forward by June 13, 1988, additional information on the remaining safety-related relief valves.
Two Unit I and three Unit 2 IST Program relief valves had setpoints exceeding their code allowable tolerance. The Unit I valves will have their setpoints adjusted to within system design pressure prior to start-up from the current outage. The Unit 2 valves will have their setpoints adjusted during the 1989 spring refueling outage.
i Although Unit 2 will be operating with two valves 1.6% above code allowable tolerance and one valve 0.19% above code allowable tolerance, all systems will be within the l
de]ign requirements.
8805250226 880518 l6 PDR ADOCK 05000317
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1g P
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i Document Control Desk May 18,1988 Page 2 As a follow on effort, we will be reviewing our setpoint program for safety-related relief valves. Our architect / engineer will determine the correct setpoints for the relief valves. by November 1988. As this information becomes available, we will schedule setpoint adjustments for the relief valves as required.
Should you have any further questions regarding this matter, we will be pleased to discuss them with you.
Very truly yours, JAT/SRC/SMD/KBC/ dim Attachment cc:
D. A. Brune, Esquire J. E.
Silberg, Esquire R. A.Capra, NRC S. A.McNeil, NRC W. T. Russell, NRC D. C. Trimble, NRC l
1 1
l
,_ ~ _ _ _ _ _._.. _ _ _ _..
ENCLOSURE (1)
ACTIONS TAKEN IN LIEU OF SECTION XI REQUIREMENTS l
l The following relief valve data matrix (Attachment 1) has been compiled to further evaluate the relief valve setpoint error and its effect on the systems in which they are located.
The data matrix contains information for all the Section XI Class 2 and 3 IST Program relief valves except steam generator safety valves. That is, the data matrix contains information for the valves that are required to perform a specific function in shutting down the reactor to cold shutdown or in : itigating the consequences of an accident as defined in paragraph IWV-Il00 of ASME Sec' a XI.
Pertinent Sections of the data matrix au.:larified below.
ANSI /ASME Code and Class:
The ANSI /ASME original construction Code and Code Class for each system in which the relief valve
- located. The original construction Code edition for USAS B31.7 is 1969 and for USAS B31.1 it is 1967.
Design Pressure:
The design pressure for each system as listed in the Bechtel design documents.
Back Pressure:
1he back pressure for each valve as a result of performing field walkdowns of each valve and reviewing the valve design documentation.
Accumulation:
Percent accumulation as listed in the valve design documentation.
As-Left Relieving Pressure:
Actual relieving pressure of the valve obtained by considering the as-left setpoints listed in Plant Testing Records and back pressure values as listed in the data matrix.
Code Tolerance:
The setpoint tolerance allowed by the Code during a
test lift of the valve.
That is 3 percent for setpoints greater than 70 psi.
It is important to note that the design criteria, design conditions, and the pressure design of components for USAS B31.7 Class 11 and til systems shall be in accordance with USAS B31.1-1967 as stated in Chapter 2-11 and 3-11 of USAS D31.7. Therefore, the design rules of USAS B31.1-1967 are applicable for all the systems listed in the data matrix with the exception of the Safety injection Tanks. The design criteria, conditions, and pressure design of Safety injection Tank components shall be in accordance with ASME Section 111 Class 11. _________
1 8
e ENCLOSURE (1) i ACTIONS TAKEN IN LIEU OF SECTION XI REQUIREMENTS l
Paragraph 102.2.4 of USAS B31.1-1967 states that:
"It is recognized that variations in pressure and temperature inevitably occur and, therefore, the piping system shall be considered safe for occasional operation for short periods at higher than the design pressure or temperature.
Either pressure or temperature, or both, may exceed the design values if the stress in the pipe wall calculated... does not exceed the S-value allowable... by more than the following allowance for the periods of duration indicated:
1.
Up to 15 percent increase above the S-value during 10 percent of the operation period.
2.
Up to 20 percent increase above the S-value during one percent of the operating period."
NOTE:
A system condition challenging a relief valve would not occur more than one percent of the operating period. lists the stress analysis results for each system and the resulting additional stress due to the relieving pressure being higher than system design pressure. The additional pressure stresses due to as-left relieving pressures listed in Attachment 2 were calculated using data from Attachment 1, the valve data matrix.
The most limiting valve, that is the valve with the highest relieving pressure compared to system design pressure, was used for each system for each unit to calculate the additional stresses., titled Maximum OBE Stress, lists an allowable stress of 1.2S as stated in Paragraph 102.2.4 of USAS B31.1-1967. It is clear that the system stresses remain below the Code allowable stresses.
Therefore, the relief valves continue to meet their design function of providing overpressure protection to the systems. Likewise, the piping systems meet n!! the requirements of the original Construction Code, USAS B31.1, and remain capable of performing their design function.
Although not required by USAS B31.1-1967, other components were considered during the evaluation process to determine the stress increase due to the relieving pressures listed in the data matrix. The results of our evaluation are summarized below for each component.
2-
7, _ _ - _ _ _ _ _ - _ _ _ _ _ _
ENCLOSURE (1)
ACTIONS TAKEN IN LIEU OF SECTION XI REQUIREMENTS 1.
Valves and Fittinas The ANSI design formulas for valve body wall thickness calculations incorporate a 1.5x factor into a modified hoop stress equation. In addition, the S-value for stress used in this equation is 7000 psi instead of the typical allowable stress of about 15,000 for piping. Therefore, the stresses in the piping system would be the bounding condition.
2.
Pumos Pump casing and nozzle wall thicknesses are generally greater than that of the connecting piping. The stresses due to an increase in pressure would be proportionately smaller for the former. Therefore, the piping itself would be the limiting component. In addition, the nozzle allowable loads by design are always much lower than piping system allowable loads.
3.
Ileat Exchanners The heat exchanger wall and nozzle thicknesses are generally proportionately thicker than the attached piping. Therefore, the stress increases due to an increase in pressure would be proportionately smaller for the former. Again, the piping itself would be the limiting component. The piping stresses would also bound the additional tubing stresses. This has been confirmed using hoop stress calculations for the component cooling water heat exchanger tubes. A small increase in internal pressure would have a negligible effect on other internat components. The pressure would not affect the loading on the tube sheet or other internal components. Therefore, it is concluded that the piping system is the limiting component, in addition, the nozzle allowable loads are always much lower than the piping system allowable loads.
4.
Gasket and other Lenkare Boundaries Gaskets and other leakage restricting devices are not pressure boundary or pressure retaining components and as such are not addressed by the ASME Code design rules, flowever, it is clear that gaskets and seals can withstand small increases in oressure. These components are typically relied upon to prevent l
leakage during hydrostatic pressure tests up to pressures of 1.5x design values.
Therefore, during slight overpressure conditions, these components will not adversely affect system integrity, in fact B31.1-1967 Paragraph 108.4 does not provide any pressure limit on metal-asbestos or sheet asbestos gaskets provided temperature requirements are met.
l I
In summary, the piping systems meet the design requirements as specified in bcth USAS B31.1-1967 and the Final Safety Analysis Report.
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! 1.
STIACH S T 1 thSEHICE IEST FRD6&am F.ELIE8 VALVE LAT4 MATEtt SHEET RUh CATE 05/16/BB Unli Vf4WE IFLILlLIhESilE AhSI/ASME Vt4VE $1IE ACC SET LAST AS MCI AS LEFT SYS C00E MOLE FESET NunkER l IN IkCHES CDDE & CLASS lhtET DUTLET 1
PEESS TEST LEFT FEESS RELEV LESIGN TOLERAhCE TO DATE l
Aiin LlhE SETilh6 FRESS PRESS EESET SEE N#EER ICHES IENE5 FS16 FS16 PSI PSIG FSI6 FSI h2TES l
1 AFN-4"Al M600 1.5-Hit 9-!M4 631.1 1.5 3.
10.
- 25. 11/04/86 65.
36.
115.
285.
+/-E.5 CUTAGE I
AFN-4502 M809 1.5-HBit-1007 831.1 1.5 3.
10.
- 85. 11/04/86 85.
30.
115.
285.
+/-6.5 DUTAGE 1
CVC-311 M73 4-NC16-1001 B31.7 CL 111 0.75 1.
10.
140. 05/13/25 142.
O.
142.
150.
+/-4.5 0UTAGE 1
CVC-315 f!73 4-NC16-1015 831.7 CL 111 0.75 1.
10.
150. 05/10/BG 150.
7.
157.
150.
+/-4.5 DUTAGE 3
CVC-3tB M73 4-NCit-1016 b31.7 CL 111 0.75 1.
10.
150. 05/12/00 150.6 2.
152.6 150.
+/-4.5 DUTAGE 2
CVE-321 R73 4-hC16-1017 BII.7 CL !!!
0.75 1.
10.
150. 11/07/E3 156.
4.
160.
150.
+/-4.5 DUTAGE 3
CVC-324 M73 2-CC7-lW3 B31.7 CL II 0.75 1.
16.
2900. 11/09/83 2713.
73.
2766.
2000.
+/-B4 NDNDUTAGE 1
CVC-!25 M13 2-CC7-ID02 B11.7 CL 11 0.75 1.
10.
2000. 04/29/D 2720.
73.
2793.
2800.
+/-84 40N00TAGE 1
CVC-I26 M13 2-CC7-1001 B31.7 CL II 0.75 1.
10.
2Wo. 11/08/83 2710.
73.
2783.
2000.
+/-94 NDNDUTAGE 1
51-211 R74 1Aht SEC.Ill CL 11 1.
1.5 1.
250. 04/30/88 253.
6.
253.
250.
+/-7.5 100TAGE 2
I I
$1-221
. M74 TAN.
SEC.Ill CL 11 1.
1.5 1.
250. M/11/E ; 252.
c.
252.
250.
+/-7.5 : OUTAGE 2
51-211 M74 TANK SEC.Ill CL 11 1.
1.5 1.
250. 04/30i46 253...
c.
253.
250.
+/-7.5 0UTAGE 2
1 51-241 M74 TANK SEC.Ill CL !!
1.
1.5 1.
250. 11/10/B6 250.
O.
250.
250.
+/-7.5 00TAGE 1
51-409 M74 6-El-1904 531.7 CL 11 0.75 1.
10.
1485. 05/05/B5 1481.
8 1481.
1600.
+ /-O DUTABE 1
51-417 M74 4-006-1001 911.7 CL 11 1.
1.5 10.
2505. 05/24/85 2500.
O.
2500.
2485.
</-74.5 DUTAGE 2
51-466 M74 14-605-1003 B31.7 CL II 1.5 2.5 10.
315. 11/21/E6 3a7.
6.
317.
335.
+/-10 NDNOUTAGE 1
51-469 474 14-CC14-!M4 B31.7 CL II 0.75 1.
10.
2405.- 11/17/B6 2490.
4.
2494.
2485.
+/-74.5 00TAGE 2
N0' ES
- 2. VALVE TO K RESET AT KIT SCEDULES SURVEILLANCE TEST. AS LEFT RELIEVING PRESSURE WITHIN CDE TOLEFANCE.
- 3. UNIT 1 VALVES TO E RESET DUEING CUR &ENT DUTAGE. UNIT 2 UALVES 10 BE ESET DURING THE 1969 SFR!NE REFUELING CUTAGE. AS LEFT RELIEVING PEESSIAE [ICEEDS CODE TOLERANCE.
FAGE 1 Or 2
t=!T triVE
- FL13 L LI::E !!!!
R31/A5MI l utVE SIIE iC IIT I LAST l A5 nack ';A5 LETT SYS
. CUIE P.2E EESET
- AMD, In IkCES CDLE 1 CLAS5 IL ET 6 CLTLET~ 5 FiE55' TEST iLEFT
,F3E55 FILEV CE516h TOLE 3M E 10 pt.TE AkL L14E
{
' SETTIG FRE55 FRE55 5ESET SEE IMMES l ICHE5l P516 F516 F51 F515 F515 FSI N2TESl f
e iEE E
AFa-4M1 i ns01 1.5-HP15-2604 531.1 1.5 3.
10.
- 85. 11f12185:
85.
30.
115.
2E5.
+/-E.5 GilTAGE 1
IJa-4502 P901 1.5-Hit-2M7 531.1 1.5 2.
10.
E5. 04/02/95 65.3 30.
115.3 285.
+/-6.5 00TAGE 1
l 10.l140.03/31167 l }31.7 CL 111 140.
O.
140.
150.
+/-4.5 00TAGE 1
6.75 1.
fvC-311 M61 4-hCle-20vl CVC-315 M61 4-M I6-2015 B31.7 CL 111 6.75 1.
10.
150. 11/12/E5 150.
7.
157.
150.
+/-4.5 OUTAGE 3
CVC-312 M61 4-HCit-2016 B31.7 CL 111 0.75 1.
10.
150. 03I30/87 147.
2.
149.
150.
+1-4.5
! DJTAGE 1
CVC-321 Mel 4-HC16-2017 531.7 CL III 4.75 1.
10.
150. 11/11/E5 153.
4.
157.
150.
+/-4.5
- DUTA6E 5
CVE-324 P461 2-CC7-2%3 B31.7 CL !!
0.75 1.
16.
2000. 03/31/E7 2720.
73.
2793.
20%.
+/-84 h040UTAGE 1
2-CC7-2002 531.7 CL II 0.75 1.
10.
2000. 11/05/85 2713.
73.
2786.
2800.
+/-84 60NDUTAGE I
l M61 CVC-3~5 CVC-I26 P461 2-CC7-2H1 631.7 CL 11 6.75 1.
10.
2000. 03/27/E7 2727.
73.
2800.
2000.
+/-84 NONDUTAGE 1
51-211 P462 im SEC.III CL II 1.
1.5 1.
250. 10/23/B5 258.
O.
258.
250.
+/-7.5 DUTAGE 3
51-221 M62 TW SEC.III CL 11 1.
1.5 1.
250. 03/23/87 253.
C.
253.
250.
+/-7.5 OUTAGE 2
51-231 R462 TAtt SEC.Ill CL 11 1.
1.5 1.
250. 10/23/B5
'253.
9.
253.
250.
+/-7.5 DUTAGE 51-241 l M62 IW SEC.III CL 11 1.
1.5 1.
250. 03/24/E7 253.
O.
253.
250.
+/-7.5 0UTASE 2
l931.7CL11 0.75 1.
10.
1485. 03/23/87 1485.
O.
1485.
1600.
+/-48 00TAGE 1
51-409 n462 6-0Cl-2%4 51-417 P462 6-CC6-2001 931.7 CL II 1.
1.5 10.
2505. 03/23/B7 2512.
O.
2512.
2485.
+/-74.5 DUTAGE 2
51-468 M62 14-605-2003 331.7 CL 11 1.5 2.5 10.
315. 04/02/87 316.
6.
316.
335.
+/-10 NONDUTAGE 1
51-469 M62 14-CC14-2M4 E31.7 CL 11 0.75 1.
10.
2485. 04/01/E7
?481.
4.
2485.
2485.
+1-74.5 DUTaiiE 1
e i
e
- 1. NO ACTION REDulRED. AS LEFT EELIEVING PkESSURE AT DR BELON SYSTEM DESIGN PRESSURE.
- 2. VALVE TO BE RESET At NEIT SCHEDULEB SURVEILLANCE TEST. AS LEFT RELIEVING PRESSURE WITHIN CDDE TDLERANCE.
- 3. UNIT 1 VALVES TO K RESET SURINE CURRENT DUTAEE. lalli 2 VRVES TD K RESET DURING TNE 1989 SPRING REFUELINE DUTAGE. AS LEFT RELIEvlNE PRESSURE EXCEEDS CDDE TOLERANCE.
FASE 2 0F 2
4 ATTACHMENT (2)
MAXIMUM OBE STRESS TABLE Add'l Stress Due to l
Line Size O.D.,
Highest Upset As-Left Relieving Allowable System Cale. No.
Thickness (in.)
Stress (psi)
- Pressure (osi)
Stress (osi) **
AFW U-I 80A 4.50, 0.337 10,904 0
18,000 AFW U-2 746 6.625, 0.432 11,242 0
18,000 CVC U-I 89A-1 3.5, 0.120 17,701 65.5 22,560 CVC U-2 293-A 3.5, 0.120 1I757 46 20.022 l
SIU-l 40AB 8.625, 0.148 18,093 207.4 21,6 %
SI U-2 213 6.625, 0.280 I3,086 140 19,680 l
l
- Upset Stress = Pressure Stress + Weight Stress + Seismic OBE Stress
- Allowable Stress = 1.2S (from paragraph 102.2.4 of USAS B31.1 - 1%7)
)
,(