ML20126C561
| ML20126C561 | |
| Person / Time | |
|---|---|
| Site: | Calvert Cliffs  |
| Issue date: | 03/29/1980 |
| From: | Lundvall A BALTIMORE GAS & ELECTRIC CO. |
| To: | Reid R Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML20126C564 | List: |
| References | |
| NUDOCS 8004040291 | |
| Download: ML20126C561 (18) | |
Text
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B ALTIMORE G AS AND ELECTRIC COMPANY P.O. B O X 1475 B A LTIM O R E, M A R Y L A N D 21203 Aamva c. Lu~ovm.Ja March 29, 1980 V.C E 8'at sic E M s .. , .
Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Commission Washington, D.C. 20555 ATTENTION: Mr. Robert W. Reid, Chief Operating Reactors Branch #4 Division of Operating Reactor!
SUBJECT:
Calvert Cliffs Nuclear Pov -
Units Nos. 1&2, Docket N' ' 50-318 Inservice Inspection (IS.
REFERENCES:
(a) NRC Letter Dated 10/' . R. W. Reid to Mr. A. E. Lundvali ENCLOSURES: (1) Unit 1 Lon Term Inser mir ' tion P1 ~ SWRI (2) BGL.10 Year Inservice Examination Plan, Calvert Cliffs Nuclear Power Plant, Unit 1 (3) BG&E 10 Year Inservice Exanination Plan, Calvert Cliffs Nuclear Power Plant, Unit 2 (4) Nuclear Piping Classification Summary (5) December 8,1978 Letter from Mr. A. E. Lundvall, Jr.
to Mr. Robert W. Reid, USNRC Gentlemen:
In response to reference (a) we hereby submit a description of the Inservice Inspection progran for Calvert Cliffs, Unit #1. Both Units #1 and #2 at Calvert Cliffs are currently beina inspected to the ASME Boiler and Pres-sure Vessel Code,Section XI,1974 Edition thru Summer 1975 Addenda. This program is currently being coordinated and conducted by BG&E personnel on site utilizing the services of Southwest Research Institute (SWRI) to con-duct standards. codeEnclosure acceptable (1) isexaminations in accordance a copy of the projected i with inspect'on current /procedu program for Unit 1 as 'epared by SWRI. It outlines a schedule that currently h #7 \9 appears compa: de with plant operations and code requirements for dis '\
tribution sucn that all current code examinations which are reasonably p %,-
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b 8004010 29/
l achievable will be completed. Enclosures (2) and (3) outline the in- l tended ISI program for Units 1 and 2 respectively during their initial ,
inspection interval. Enclosure (4) is submitted for your information. l l
Based on the experience gained in the course of inspections to date. l certain examination requirements specified in the code are impractical l to accomplish for a variety of reasons. These exams and any possible ;
alternatives are listed as follows for Units 1 and 2:
A. ASME Code Section XI, Item Bl.14; Category B-I-1. This requirenent i is for a Visual Examination of selected Reactor Vessel Cladding i patches. Six patches (36 in2 each), evenly distributed in accessi-ble sections of the Vessel Shell, are to receive a 100% exam every i Inspection Interval (10 years). Paragraph IWB-2411 requires that '
this exam be distributed evenly over the 3 forty-month inspection ,
periods in an Interval. >
Since these areas are inaccessible unless the Core Barrel is removed, it is intended that this examination requirement be fulfilled near the end of the Interval when the Core Barrel is scheduled for removal, .
utilizing a remote visual method. Continued Cladding integrity can ,
be verified during the Visual inspection of the Reactor Vessel Head Cladding during each Interval since the Vessel and Head surfaces are exposed to similar service environments and were manufactured under similar processes by the same vendor.
B. ASME Code Section XI, Item Bl.4; Category B-0. This requirement is for a Volumetric Examination of the Primary Nozzle-to-Vessel Welds and the Nozzle Inside Radiused section. There are six nozzles, 4 Inlet, and 2 Outlet, and of these, only the 2 Outlet Nozzles are ac- '
cessible to examine when the Core Barrel is installed. Paragraph ;
IWB-2411 requires the 2 of the 6 nozzles be examined in each of tne i 3 forty-month periods to obtain the 100% exam in each Inspection In- -
terval. However, since the Core Barrel will not be removed until ;
near the end of the Interval, the 2 Outlet Nozzles will be examined ;
during the 1st period, and the 4 Inlet Nozzles will be examined during l the 3rd period by Mechanized Methods from the I.D. when the Core Barrel l is removed.
C. ASME Code Section XI, Item Bl.2; Catetory B-B. This requirement in-cludes the Circumferential Weld in the Reactor Pressure Vessel Closure Head. This would entail access to at least 5% of the entire weld, and i should be done once during each insoection interval. However, the cluster of Control Element Drive Mechanisms penetrating the Vessel Head make this exam impractical. Therefore, it is intended that the Integrity of the Vessel Head be verified during the System Pressure Test which follows each refueling and by the Visual Examinations of the Head in- !
terior clad surface required by this code during each Interval.
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I D. ASME Code,Section XI, Item C2.1 and C2.3; Category C-G. The requirement specifies a Volumetric examination for Circumferential, -
Longitudinal, and Branch Piping Welds in the Main Steam and Feed-water systems, covering 100". of the weld. Portions of the Main :
Steam and Feedwater lines, in or adjacent to Safety Related areas '
of the Auxiliary Building are encapsulated and therefore inaccessible l for examination. These welds are: l t
Unit 1 Main Steam !
l A) 34-MS-1201-2 34-MS-1201-6/6-MS-1207 '
34-MS-1201-3 34-MS-1201-6BC-3 34-MS-1201-3LD 34-MS-1201-7LU 34-MS-1201-4LU 34-MS-1201-7 ,
34-MS-1201-4 34-MS-1201-7LO-1 i 34-MS-1201-4LD-1 34-MS-1201-7LD-2 !
34-MS-1201-4LD-2 34-MS-1201-8LU-1 l 34-MS-1201-5LU-1 34-MS-1201-8LU-2 l 34-MS-1201-5LU-2 34-MS-1201-8 34-MS-1201-5LD 34-MS-1201-9 !
34-MS-1201-6 34-MS-1201-9LD-1 !
34-MS-1201-6LD 34-MS-1201-9LD-2 34-MS-1201-6BC-1 34-MS-1201-10LU-1 !
34-MS-1201-6BC-2 34-MS-1201-10LU-2 !
34-MS-1201-10 .
B) 34-MS-1202-2 34-MS-1202-6LU i 34-MS-1202-3 34-MS-1202-6 !
34-MS-1202-3LD 34-MS-1202-6LD i 34-MS-1202-4LU 34-MS-1202-7LU :
34-MS-1202-4 34-MS-1202-7 ;
34-MS-1202-4LD-1 34-MS-1202-8LU 34-MS-1202-4LD-2 34-MS-1202-8 l 34-MS-1202-SLU-1 34-MS-1202-8LD-1 !
34-MS-1202-5LU-2 34-MS-1202-8LD-2 l 34-MS-1202-5 34-MS-1202-9LU-1 ;
34-MS-1202-5LD 34-MS-1202-9LU-2 l 34-MS-1202-5/6-MS-1208 34-MS-1202-9 i 34-MS-1202-5BL-1 34-MS-1202-11 !
34-MS-1202-5BC-2 34-MS-1202-11LD-1 l 34-MS-1202-5BC-3 34-MS-1202-11LD-2 l 34-MS-1202-12LU-1 !
34-MS-1202-12LU-2 l 34-MS-1202-12 i 34-MS-1202-12LD l Main Feedwater A) 16-FW-1201-1 16-FW-1209-1 16-FW-1201-1BC 16-FW-1209-2 16-FW-1201-2 16-FW-1209-3 l 16-FW-1201-3 16-FW-1209-4 !
16-FW-1201-4 16-FW-1209-5 j l
i Main Feedwater (Cont'd) 16-FW-1209-6 16-FW-1209-13 16-FW-1209-7 16-FW-1209-14 :
16-FW-1209-8 16-FW-1209-15 t 16-FW-1209-9 16-FW-1209-16 l 16-FW-1209-10 16-FW-1209-17 )
16-FW-1209-11 16-FW-1209-18 f 16-FW-1209-12 !
B) 16-FW-1202-1 16-R4-1210-1 16-FW-1202-1BC 16-FW-1210-2 !
16-FW-1202-2 16-FW-1210-3 i 16-FW-1202-3 16-FW-1210-4 !
16-R4-1202-4 16-FW-1210-5 i 16-FW-1202-4BC 16-FW-1210-6 l 16-FW-1202-5 16-FW-1210-7 l 16-R4-1202-6 16-FW-1210-8 !
16-FW-1202-7 16-FW-1210-9 !
16-FW-1202-8 16-FW-1210-10 :
16-FW-1202-9 16-FW-1210-11 !
16-FW-1202-10 16-FW-1210-12 i 16-R4-1210-13 !
Unit 2 Main Steam j f
A) 34-MS-2001-1LU 34-MS-2001-3LU 34-MS-2001-1 34-MS-2001-3 34-MS-2001-1LD-1 34-MS-2031-3LD-1 1 34-MS-2001-1LD-2 34-MS-2001-3LD-2 l 34-MS-2001-2LU-1 34-MS-2001-4LU-1 !
34-MS-2001-2LU-2 34-MS-2001 4LU-2 l 34-MS-2001-2 34-MS-2001-6LD-1 1 34-MS-2001-2LD 34-MS-2001-6LD-2 j 34-MS-2001-2/4-MS-2009 34-MS-2001-7 i 34-MS-2001-2/6-MS-1007 i B) 34-MS-2002-1LU 34-MS-2002-3LD-2 !
34-MS-2002-1 34-MS-2002-4LU-1 l 34-MS-2002-1LD-1 34-MS-2002-4LU-2 34-MS-2002-1LD-2 34-MS-2002-4 34-MS-2002-2LU-1 34-MS-2002-4LD-1 !
34-MS-2002-2LU-2 34-MS-2002-4LD-2 !
34-MS-2002-2 34-MS-2002-4BC-1 l 34-MS-2002-2LD 34-MS-2002-4BC-2 ;
34-MS-2002-2/6-MS-2008 34-MS-2002-6LD-1 i 34-MS-2002-2/4-MS-2010 34-MS-2002-6LD-2 ;
34-MS-2002-3LU 34-MS-2002-7 1 34-MS-2002-3 34-MS-2002-7LD 34-MS-2002-3LD-1 34-MS-2002-8 l
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Unit 2 Main Feedwater A) 16-R4-2001-1 16-Bl-2001-2 16-DI-2001-3 i
B) 16-RJ-2002-1 l 16-FW-2002-2 16-FW-2002-3 i 16-FW-2002-4 r 16-FW-200?-5 i 16-FW-2002-6 l t
16-FW-2002-7 16-FW-2002-8 :
16-Rl-2002-9 i C) 16-FW-2009-1 l 16-FW-2009-2 [
16-FW-2009-2A 16-FW-2009-3 i 16-FW-2009-4 16-FW-2009-5 -
16-FW-2009-6 !
16-FW-2009-7 i 16-Pd-2009-8 16-FW-2009-9 i 16-FW-2009-10 16-FW-2009-11 i 16-FW-2009-12 16-FW-2009-13 D) 16-FW-2010-1 ,
16-FW-2010-2 '
16-FW-2010-2A -
16-FW-2010-3 16-FW-2010-4 16-FW-2010-5 16-P4-2010-6 :
16-FW-2010-7 16-FW-2010-8 l 16-FW-2010-9 I
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I However, in accordance with the Technical Specifications for both units (Paragraph 4.4.10.1.2),100% of the Unencapsulated Welds on Main Steam or Feedwater lines greater than 4" in nominal diameter, t in or adjacent to Safety Related areas of the Auxiliary Building, ;
will be examined during each inspection interval. l The fiain Feedwater line encapsulation does not allow this option.
However, the Main Steam Line has a number of accessible locations.
These welds, although not required to be tested in many cases, per the guidelines in Regulatory Guide 1.26, will be examined such that all of the listed welds will be examined every 10 years, instead of just the i 100% coverage over the 40-year life of the plant currently recuired by code. These additional welds, examined at a higher frequency will pro- l vide adequate indication of the piping conditions existing. l The following welds will be examined: l E
Unit 1 Main Steam A) 34-MS-1201-8LD-1 34-MS-1201-12 l 34-MS-1201-8LD-2 34-MS-1201-12LD
- 34-MS-1201-8BC-1 34-MS-1201-12BC
- 34-MS-120;-8BC-2 34-MS-1201-13LU
- 34-MS-1201-10LD* 34-MS-1201-13LD-1*
34-MS-1201-11LU* 34-MS-1201-13LD-2* i 34-MS-1201-11
- I 34-MS-1201-14LU-1*
34-MS-1201-llLD* 34-MS-1201-14LU-2* l 34-MS-1201-12LU* j B) 34-MS-1202-9tD-1 34-MS-1202-15LU * !
34-MS-1202-15
- 34-MS-1202-9LD-2 !
i 34-MS-1202-9BC-1 34-MS-1202-15LD
- 34-MS-1202-9BC-2 34-MS-1202-16LU
- l 34-MS-1202-10LU-1 34-MS-1202-16 34-MS-1202-10LU-2 34-MS-1202-16LD j 34-MS-1202-10 34-MS-1202-16BC * !
34-MS-1202-12LD* 34-MS-1202-17LU
- i 34-MS-1202-13LU* 34-MS-1202-17 !
34-MS-1202-13LD* 34-MS-1202-17LD-1*
34-MS-1202-14LU* 34-MS-1202-17LD-2* [
34-MS-1202-14
- 34-MS-1202-18LU-1* <
34-MS-1202-15LD* 34-MS-1202-18LU-2* l t
Unit 2 Main Steam A) 34-MS-2001-4 34-MS-2001-8BC 34-MS-2001-4LD-1 34-MS-2001-9 .
34-MS-2001-4LD-2 34-MS-2001-9LD-1 * [
34-MS-2001-9LD-2
- 34-MS-2001-4BC-1 34-MS-2001-4BC-2 34-MS-2001-10 i 34-MS-2001-6 34-MS-2001-10LD-1* i 34-MS-2001-7LD
- 34-MS-2001-10LD-2* l 34-MS-2001-8 i 34-MS-2001-8LD * !
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i B) 34-MS-2002-6 34-MS-2002-10LD-1* !
34-MS-2002-8LD 34-MS-2002-10LD-2*
34-MS-2002-9
- 34-MS-2002-11 i 34-MS-2002-9LD* 34-MS-2002-11LD-1* j 34-MS-2002-9BC* 34-MS-2002-11LD-2* :
34-MS-2002-10
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- Designates welds in the examination program which would not other- i wise require examination per the guidelines established in Regulatory Guide 1.26, 1 E. ASME Code,Section XI, Subsection IWB f Paragraph IWB-2410 requires a hydrostatic test of Class III systems i once every Inspection Interval. This would require that lines asso- !
ciated with the Diesel Generators; i.e.,HB-4, Fuel Oil; HB-5, Lube l 011; HB-22, Cooling Water; HB-51, Diesel Starting Air; be examined }
while at a hydrostatic pressure of 1.10X Design Pressure. Such a !
test could not only place the Diesel, which is intended as an emer- !
gency power source, out of service, but could also contaminate air i and oil lines. :
However instrumentation exists to monitor the critical parameters i and is recorded at the frequencies listed: [
r Starting Air Receiver Pressure: 6 times per day !
11 and 21 Fuel Oil Tank Levels: 6 times per day ;
Fuel Oil Temperature and Specific Gravity: 6 times per day ,
Additionally,the Diesels are run a minimum of once per week under .
load for at least I hour. During this condition, the following !
readings are also recorded: (In addition to readings 15 minutes !
and I hour after start). l Generator Bearing Temperature: 6 times per day i Coolant Pump Discharge Pressure: 6 times per day Lube Oil Pressure: 6 times per day Jacket Cooling Inlet Temperature: 6 times per day ;
Jacket Cooling Outlet Temperature: 6 times per day i Lube Oil Inlet Temperature: 6 times per day ,
Lube Oil Outlet Temperature: 6 times per day l The Monitoring of the above parameters in addition to the Inservice i Leak Test required every 40 months which will be performed on all !
piping which is not underground or internal to the Diesel will pro- !
vide a high degree of confidence in the integrity of the Diesel Gen- l erator systems. This will eliminate the need for the Hydrostatic 7 Pressure Test required every Interval. j i
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F. ASME Code,Section XI, Subsection IWD.
Paragraph IWD-2410 requires a hydrostatic test of Class III systems ,
every Inspection Interval to 1.10 x Design Pressure. On installed j Salt Water Cooling Systems, (Pipe Classes LC-2, LJ-1, and MC-6) only !
Butterfly Valves are installed. These valves are insufficient to l maintain a satisfactory pressure boundary to sustain the increased l pressure. Therefore the hydrostatic pressure test at elevated pres- ;
sure cannot be completed. However, the Inservice Leak Test required ;
every 40-month Inspection Period will be perfomed on a yearly basis !
on above-ground portions to verify continued system integrity. l G. ASME Code,Section XI Subsection IWD. !
i Paragraph IWD-2410 requires a hydrostatic test of Class III systems ;
every Inspection Interval to 1.10 x Design Pressure. On the Service t Water System (HB-22) main headers, where Butterfly Valves are in- ;
stalled, sufficient seal to maintain pressure on an isolated portion ;
of the system cannot be achieved. For this reason the elevated pres- l sure hydrostatic test cannot be completed. However, the Inservice !
Leak Test required in every 40-month Period will be accomplished and '
will serve to verify continued system integrity. This inspection will, however, be performed at an increased frequency such that the system is examined on a once a year rather than once per 40 months basis.
4 H. ASME Code,Section XI, Subsection IWD.
Paragraph IWD-2410 requires a hydrostatic test of Class III piping -
systems to 1.10 x Design Pressure once every Inspection Interval. l Certain portions of Non-nuclear systems have been classified as [
Nuclear, Class III per current guidelines, if they penetrate the t Containment liner. These line segments are listed below and will !
not be hydrostatically tested per IWD-2410 and IWD-5000. They are, )
in fact, included in the Local Leak Rate Test program required by I current Technical Specifications, and under this program, receive [
a pressure test at least every refueling cycle to verify their in- ;
tegrity. This pressure is at least 50 psi, and is intended to prove that the penetration can at least meet the requirements on the Con-
- tainment for pressure retaining capabilities. l l
The classification and system descriptions are as follows: .
EC-2 Themocouple Piping on Main Steam Penetration Piping l GB-24 Auxiliary Steam to the Contaminated Washdown Area Penetration Piping ,
HB-43 Plant Air Penetration Piping HB-44 Instrument Air Penetration Piping i HB-45 N2 Penetration Piping HB-52 Fire System Penetration Piping (NFPA Codes) -
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I HB-57 Containment Heating Penetration Piping l HB-60 Plant Water Penetration Piping j HB-65 Containment Atmosphere Radiation Monitor ,
Penetration Piping l
HC-8 Demineralized Water Penetration Piping f
HC-43 H2 Samoling and Containment Pressure Indicator !
Penetration Piping {
I. Enclosure 5 is also submitted to incorocrate a relief previously I requested for the 20f. DAC evaluation criteria. All the necessary i technical information stated in that letter continues to be appli- !
cable.
J. Paragraph IWB-2410 requires a hydrostatic test of Class III systems once every Inspection Interval. This would require that the Main ,
Steam Isolation Valve hydraulic actuator lines be tested hydrostat- !
ically to 1.10 x Design Pressure. To prevent possible contamination i of these lines it is intended that this pressure test not be done, ;
but that system integrity be verified by the Inservice Leak Test !
required once every 40 month Period.
K. Paragraph IWA-5210 requires that when conducting pressure tests, pressure shall be maintained for at least 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> in accordance ,
with the 1974 Edition of Section XI thru Surrer 1975 Addenda, j However, the 1977 Edition of Section XI, thru the Summer 1978 !
Addenda, has been approved for use per the October 19, 1979 re- !
vision to 10 CFR 50.55a. In this edition, paragraph IHA-5213 l requires a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> hold time for insulated systems, but permits a hold time of 10 minutes for uninsulated systems. Also this shorter hold time will provide for a reduced exposure to test !
oersonnel when workina in controlled area. Therefore the 10 minute hold time will'be applied to pressure tests on uninsulated l oiping systems. !
This progran identifies the examinations which should be able to be per- i formed to conform to code requirements, or the necessary deviations as l we have identified them to date. Should further clarification or devi- i ations become necessary we will inform you as they are identified. {
If you have any further questions please do not hesitate to contact us. {
i Very truly yours", t A. E. Lundvall, Jr.
f AEL/TLS/gfc i
cc: Messrs. J. A. Biddison, Esquire ttr. E. L. Conner, Jr. (!!RC) ;
G. F. Trowbridge, Esquire Mr. Glenn Walton, NRC (King of Prussia) !
All (w/o Encl 1) j i
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Enclosure 2
- ... . 1 S ALT" - E S. - EL.CTDIC ST'.:A1Y I C YE A; I ;SE T '.': CE EXA'4!:MTIO*. PLAT; CALVERT CLIFFS '!UCLEAF. PO'!EP. PLANT UNIT 1 >
I InsEction Interval: May 8,1975 te fiay 8,1985 ;
Inscection Feriod: Septer,ber 8,1978 to January 8,1988
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Submitted: ,
_ e ! 3 6 7f ISI r r u ir-tor i Cate Revision: 1 Approved: % _ ' 3 - //- 79
" na g er , D a i '1 g c. surance Dept.
La:e
. Revision: 1 Approved: b Cnief Engineer m u2/ '
4[13 /?r Date ' ;
Calvert Cliffs Nuclear Power Plant l Reviewed: POSRC No.: 7f 38 !
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Enclosure 2
- evisinn 1 :-
- 1. REFENE'ZE3 A. Lonc-Te r :rservice Examina ion ':r Class 1, Cit:: :, in-Class 2 Systems and Components for ;; .er: Cliffs ':uclear ;ower Plant, Uni: 1 (currently prenared by Southwest Pesearch :nstitute) i E. Regulatory Guide 1.83 (U.'S. Nuclear Reoulatory Commission)
C. ASiiE Boiler & Pressure Vessel Code,Section XI 1974 Edition, thru l Summer 1975 Addenda. i D. Technical Specifications, Unit 2, Saltimore Gas and Electric Company's Calvert Cliffs Nuclear Power Plant, Final Safety Analysis Report.
II. PLAN
- 1. This document is presented to outline the Inservice Inspections to be performed over a 10 year period on Baltinore Gas and Electric l
Company's Calvert Cliffs Nuclear Power Plant, Unit 1. Components or areas to be inspected, were selected,'accordance with references .
(a) thru (d) and their associated docunents. ,
- 2. Reference (a) prcvides a projected general schedule, revised from that in effect during the first 40 nonths of operation, that will ensure all exaninations required by reference (c) are accomplished within the allotted time and with a reasonable time distribution.
- 3. Nondestructive examinations will be performed in accordance with i procedures conforming to the requirements of references (c) and (d) and which have received the review and approval of SG&E's Principal !'.etallurgist. -
Procedures used and examinations performed by vendors or contractors will comoly with a quality Assurance Program perviously aporoved ,
by the Quality Assurance Department, Baltimore Gas and Electric !
Company, or with procedures listed under the BG&E Quality Assurance Program. ;
- 4. Exaninaticr. results and any indications shall also be evaluated utilizing ac:eptance criteria stated ir, reference (c) for all welds, and in references (b) and (d) for Steam Generator tube i exauinations. The DG&E Nondestructive Examination program contains .
additional acceptance criteria f.or areas not specific. ally covered by
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these references. :
- 5. References (b) and (d) state the requirements for scheduling the examination of Steam Generator tubes from the I.D. Utilizing the Eddy Curren:' technique. These req'uirements will be met and ccheduled based on previous exam results. _
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Enclosure 2 Revision 1 3 l
- 6. Reactor Vessel Internals examinations will be scheduled and ,
perforned to comply with the requirements stated in Categories E ':-l and B-N-3 of reference (c). This exam uill conform to i procedures prepared in accordance with Calver: Cliffs Instructions. [
- 7. Pressure Testing of Class 1, 2, and 3 systems as required by [
reference (c) will be identified and scheduled in a separate !
procedure to ensure completion durina the recuired time limits.
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- 8. Pump and Valve Testing required by reference (c) will be identified, scheduled, and performed in accordance with QAP-16, " Surveillance .
Testing". ,
- 9. This procedure presents a general outline of the examinations to be ;
conducted to coincide with scheduled refueling or other outages.
It is intended that in all cases code requirements will be met. ,
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i Encloure 3 !
l REVISION O 1 :
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' l BALTIMORE GAS & ELECTRIC COMPANY . !
10 YEAR' INSERVICE EXAMINATION PLAN l 1
CALVERT CLIFFS NUCLEAR' POWER PLANT f l
UNIT 2 !
i FOR THE INTERVAL: 1 April 1977 to 1 April 1987 f INSPECTION PERIOD: 1 April 1977 to 1 August 1980 f I
SUBMITTED: #' [-/d-7f ISI Coorcinator Date i I
0 REVISION: 0 APPP,0VED: e. bh Manager, Quality Assurance Dep't.
k- /- N Date g
REVISION: O_ APPROVED: #A 9-6-76 i -
Chief Engineer, Date j Calvert Cliffs Nuclear Power Plant i l
l 1
e REVIEWED:
POSRC NO.: 78'//7.. !
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Enclosure 3 i REVISION O 2 ..
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i I, REFERENCES .
l (a) Long-Term Inservice Examination Plan for Class 1. Class 2, and . .
Class 3 Systems and Components for Calvert Cliffs Nuclear Power ;
Plant, Unit 2. (Southwest Research Institute) i (b) Regulatory Guide 1.83 (U.S. Nuclear Regulatory Commission) ,
l (c) ASME Boiler and Pressure Vessel Code,Section XI,1974 Edition .
thru Sunner 1975 Addenda.
i (d) Technical Specifications, Unit 2, Baltimore Gas and Electric l Company's Calvert Cliffs Nuclear Power Plant, Final Safety l Analysis Report, j t
i II. ;
- 1. The following plan is presented to identify the Inservice f examinations to be performed over. a 10 year period on i Baltimore Gas and Electric Company's Calvert Cliffs Nuclear l Power Plant Unit 2. Components or areas to be inspected -
were selected and scheduled for examination in accordance with references (a) thru (d) and their associated documents.
- 2. Reference (a) provides a projected general schedule to ensure l all the examinations required by reference (c) are accomplished
- within the allotted time and with a reasonable time distribution. ;
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- 3. Nondestructive examinations will be perfonned in accordance l with procedure specified in reference (c). ,
i Procedures and examinations performed by vendors or contractors I will comoly with a Quality Assurance Program previously approved ,
by the Quality Assurance Department, Baltimore Gas and Electric !
Company or with procedures listed under the BG&E Quality Assurance i. i Program. ;
. 4 Examinatiori results and any indications shall also be evaluated !
utilizing acceptance criteria stated in reference (c) for all -
Non Destructive Examination of Welds, and in references (b) and ;
(d) for Steam Generator tubes examinations. i References (b) and (d) state the requirements for scheculing !
, 5.
the examination of Steam Generator tubes from the I.D. utilizino i the Eddy Current technique. These requirements will be met and :
scheduled based on previous exam results and unit outa'ges. j
t
. Enclosure 3 REVISION O 3 I
i
- 6. Reactor Vessel Internal examinations wi.ll be scheduled and per-formed to comply with the requirements stated in examination category B-N-1 and B-N-3 of reference (c). This exam will con-form to procedures-prepared in accordance with CCNPP instructions.
7.. Additional piping and component supports not required by reference (c) are not covered by reference (a) and will be scheduled and performed on an outage basis by BG&E personnel.
- 8. Pressure Testing of Class 1, 2, and 3 systems as required by re-ference (c) will be identified and scheduled in a separate pro-cedure to ensure completion during the Ellotted intervals.
- 7. Pump and Valve Testing required by reference (c) will be identified scheduled, and performed in accordance with QAP-16, " Surveillance Testing."
- 10. This procedure presents a general outline of the examinations to be conducted to coincide with scheduled Refueling or other Outages. It is intended that in all cases code requirements will be met.
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" NUCLEAR PIPING CLASSIFICATION
SUMMARY
" Enclosure 4 PIPE CLASS DWGS REFERE' ICE DWG(s) !
CLASSIFICATION CODE DESCRIPTION U-1 U-2 l CC-1 I Reactor Coolant M-72 M L60 ,
CC-2 I Pressurizer Surge Pipe M-72 M-h60 i CC-3 I Letdovn Flov to Control Valve M-72,73 M-h60,h61 :
CH516 i CC-k I Safety Injection from 2nd Valve M-72,7h M h60,h62 l to Reactor Coolant kop i CC-5 I Isolation Valves Downstream of the M-72,73 M-h60,h61 '!
Regenerative Heat Exchanger to i Reactor Coolant k op
~
. CC-6 II Redundant EPSI System M-73,7h M-h61 h62 CC-7 II Charging Pump Discharge to the M-73 M h61 .
Isolation Valves downstream of j the Regenerative Eeat Exchanger .
CC-8 II RCS Auxiliary Piping M-66 M-66 l)
CC-9 I RCS Drains & Vents (to 2nd Valve) M-72 M-h60 Hot and Cold Legs and S/G differential I pressure piping CC-10 I Pressurizer Safety and Relief Valve M-72 M h60 Piping (Upstream of Valves) i CC-11 I Pressuriter Spray System M-72 M-h60 !
CC-12 II RCP Controlled Bleed-Off M-51,73 M-h52,h61 !
, CC-13 II Safety Injection Upstream of 2nd M-Th M L62 l I
Isolation Valve from Loop !
CC-lh I Shutdown Cooling thru Isolation M-72,Th M h60,h62 Valves t
CC-15 II Letdown from Control Valve CH516 M-73 M h61 !
4 to Letdown Control Valves !
CC-16 I RCS, Pressuricer End, Hot Leg and M-66 M-66 i Cold Leg Portion ,
CC-17 I RCP differential pressure piping M-72 -M h60 l
DB-1 II Feed Pump Discharge to Steam Gener. M-39 M-ho !
' ator !
DB-3 II Feedvater Penetration Piping M-39 M-ho l DC-1 II HPSI to Primary Loop, Upstream M-Th M-k62 of Flow Control Valve l i
DC-2 II Safety Injection recire to RWT M-Th M-h62 l E3-1 II Main Steau to H.P. Turbine Stop M-35 M-36 !
E3-5 -
III Aux. Feed frvm S/G Aux Feed M-39 M ho j Pu.p j l ES-6 II 31ovdown Piping (exel penetration) M-35 M-36
) E3-7 III Aux. Feed Pu p Recire M-39,59 M ho,59 E3-8 III Aux. F6ed Pu=p Turbine Steam M-35 M-36 i
. Supply l E3-12 II Main Steam Pipe between Liner M-35 M-36 !
and Isolation Valve i E3-13 II Aux Feed Penetration Pipe M-39 M ho
]
EB-lk II S/G 31ovdovn Penetration Pipe M-35 M-36 .
EC-1 III Letdown Control Valve to Back- M251,73 M-h52,h61 pressure Valves EC-2 Ther=occuple Piping .on Main II Steam Penetration Pipe G3-2h III Aux. Steam to Contaminated M-77 Sh 2 M-77 Sh 2 Washdown Area Penetration Piping e
- p- y - , - , -- -.----erre
" NUCLEAR PIP 2NG CLASSZFlCATION
SUMMARY
" Enclosure 4 -
. REFERENCE DWG(s)
CLASSIFICA"' ION CODE DESCRIPTION U-1 U-2 GC-1 II LPSI Pu_p Discharge System to M-Th M-h62 Reactor Coolant Loop Upstream of Flow Control Station GC-2 II Ct=t Spray Pu=p Discharge M-7h M-h62 (to Isol. Valve)
GC-3 II HPSI Pu=p Suetion from Shutdown M-Th wh62 Heat Exchanger Discharge GC-4 II N2 to Safety Injection Tanks M-7h M h62 GC-5 II Reactor coolant to LPSI Pump 5 74 M-k62 Suction, Shutdovn Cooling GC-6 II Safety Injection Tanks, Aux. M-Th M-h62 Piping .
GC-7 II Safety Injection and Contain:nent M-Th M h62 Spray Pu=ps, Recire to RWT GC-8 II Pressurizer Safety and Relief Valve M-72 M h60 Header & Safety Valve Piping downstream of Valves GC-9 II Safety Injection Tank to Outlet M-7h M h62 Check Valve HB-3 III Component Cooling Water M-51 M-h52 -
Penetration Pipe H3 h III Lube Oil (pickled pipe) M-69 M-69 H3-5 III Puel Oil (pickled pipe) M-69,79 M-69,79 EB-18 III Service Water Penetration Pipe M-h6 M h7 H3-19 III S/G Aux. Feed Pump Suetier M-39,59 M ho,59 EB-22 III Service Water (exel. Turbine M h6,69 M-h7,69 Bldg) .
H3-23 III component Cooling M-51,73,77(1)M h52,h61,77(1)
HB-h3 III Plant Air Penetration Wh79 (2) M h79 (2)
HB hk III Instrument Air Penetration M-53 Wh5h EB-h5 III N2 Penetration Pipe M-68 M-68 -
HB-51 III Diesel Air Start System M-69 M-69 H3-52 III Fire Syste= Penetration Pipe M-56 M-56 H3-57 III Ct=t Heating Penetration Pipe M-71 (2) M-71 (2)
EB-60 III Plant Water Penetration Pipe M-h79 (2) M-h79 (2)
H3-65 III Ct=t Atmosphere Radiation Monitor Penetration Pipe HB-66 III H2 Purge Penetration Pipe EB-67 III H2 Purge System H3-68 III IRLT Penetration Pipe EB-69 III 3ackup for S/G Aux. Feed Pump M-59 W59 H3-Th III Spare Penetration Caps HC-3 II Engineered Safeguards Pu=ps Suetion M27h M-k62 -
HC-h III Spent Fuel Cooling M-58,73,7h M-58,h61,h62 HC-6 II Scric Acid Pu p Suetion M-73 M h61 HC-7 .II Boric Acid Pu=p Discharge to M-73 M-h61 Charging System HC-8 III De=ineralined Water Penetration PipeW61 M-61 ,
HC-16 II VCT te Charging Pumps M-73 M-h61 HC-19 III Prom Letdown Pressure Control M-73 M h61 to VCT L HC-21 II RCP Controlled 31eed-Off to R.C. M-73,77(1) M h61,77(1)
Drain Tank-l C
l i
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_. . ~ . - - . . . . . . - . - . - - . - . - _ - . _. - - . _ . . .- - - . _ . - - . . - _
" NUCLEAR PfPING CLASS 1FICATION
SUMMARY
a Enclosure 4 !
REFERENCE DWO(s) j CLASSIFICATION CODE DESCRIPTION U-1 U-2 ;
HC-23 III RWT Plscellaneous Pipe M-Th M-h62 HC-2h III Quench Tank Relief and Drain M-72 M h60
'HC-26 III- Charging Pu=p Relief Drains HC-27 III RCP Vapor Seal Leakage M-51,77(1) M-h52,77(1)
HC-31 III RCP Controlled Bleed-Off to VCT M-73 M-h61 i HC-33 II Ct=t Spray Piping (Downstrea= M-Th M h62 of Isolation Valve) -
HC-36 III Rad-Waste and Refueling Pool - M-77(1) M-7T(1) ;
Penetration & Ct=t Su=p Drain ,
Penetration Piping !
HC-38 II Charcoal Filter Spray Piping M-52,73 M-h53,h61 !
HC-ko III VCT Miscellaneous Pipe M-h61 M-73 l (Lines = 3-EC-ho-1001, 3-HC-ho-1003, i 3-HC-h0-2001, 3-HC-40-2003) !
HC-h3 III Hydrogen Sa=pling & Ct=t Pressure M h63 M-h63 I Indicators, Penetration Pipe !
HC h8 III Charging Pu=p Seal Lubrication -
Syste= l t
LC-2 III Salt Water (Underground)
LJ-1 Mh9 M-h50 i III Salt Water ( Above Ground) M h9 MC-6 M-h50 III Salt Water to ECCS Pu=p Roe: M Lp M h50 Coolers & to Isolation Valves to Cire Vater Pu=p Roc = Coolers I i
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_=__,- - . . - - . _ . . - - . . . . . . - _ - _ _ _ . - ,_, , _ - . . _ . - . _ . . - - . . - - . . . - ---.t
20% % C - (d.lM{ Olfute (
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, BALTI M O RE G AS AN D ELECTRIC CO M PANY -
G AS AN D ELCC*rmC B W LO W O Enclosure 5 f B ALTI M O R E, M A RYLA N D' 212 0 3
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i As'Twum E. Luw pvALL.Jm.
December 5, 1978 '
v.c . m. . .. .
so . ,
Office of Nuclear Reactor Regulation i U. S. Nuclear Regulatory Co==ission !
. Washington, D. C. 20555 l Attn: Mr. Robert W. Reid, Chief $
1 Operating Beactors Branch ph "
l Division'of Operating Reactors l i
Subject:
Calvert Cliffs Nuclear Power Plant . l Units Nos. 1 & 2, Docket Nos. 50-317 & 50-318 l Inservice Inseeetion (ISI) P ocra: '
t 1
Gentlemen. t l
, The ASMI Boiler and Pressure Vessel Code,Section XI currently requires that Class 1 and 2 piping be examined to fulfill the requirement j for an Inservice Inspection of Nuclear Components. All piping, Class 1 and .
2, is to be examined using the exa=ination =ethods listed in Table IWB-2600 [
(Class 1) and IWC-2600 (Class 2). Where volumetric examination is required, ultrasonic inspection is utilised due to restrictions imposed by using i radiography. Piping examination by ultrasonic testing is to be done per i the provisions of Article 5 of Section V of the ASME code, since Appendix !
I of Section XI applies only to Class 1 and 2. ferritie vessels, 21/2. inches i and over in vall thickness. ,
Article 5 of Section V requires that all indications vith a !
response greater than 20 percent of the reference level she.11 be investigated ;
to the extent that the operator can evaluate the shape, identity, and loca- l tion of all such reflectors.
- The above require =ent becomes burdensome due to the nu=ber of ,
irrelevant indications which could occur in this region due to noise. !
Additional difficulties arise because extra exa ination teams with exa=iners who are qualified Level II (or better) =ust be utilized. "'he use of these highly qualified examiners to record and evaluate indi'entions which are not *
, associated with true defects results in two undesireable conditions:
5
- 1) The,. examiners are not available time-vise to conduct meaningful !
inspections; j
- 2) The ext =iners are unnecessarily exposed to radiation which l increases their total man-re= burden and reduces their ultimate l availability for future examinations in high radiation areas. ';
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'. . . i Enclosure 5_ *
- t l
. In light of the above, we propose the following alternative ;
criteria to Article 5 of .9ection V of the Code: '
t l
All evaluations which exceed 100 percent of reference level vill -!
be evaluated, and all indications which exceed 50 percent of reference l 1evel vill be. recorded for future reference, as necessary. For vessels "
with >21/2 inches of vall thicknesn, the evaluation ' requirements of Appen- !
. dix I,Section XI of the ACME Code vill continue to anply. -[
\
We have discuar,ed these new criteria vith Mr. Glenn Walton of the ;
Office of Inspection and Enforcement, llegion I, and he has informed us j that his office vill consider the criteria to be in effect as of the mailing - !
date of this letter. For record purposes, it is our intention to formally ;
implement the revised criteria as of .Tanuary 1, 1979, and ve,.therefore, !
ask your concurrence prior to that date. j 4
I Very truly y ,urs,
- } +
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~? M.
i
& S. O )-
s ~; y u ,
l I
l7 i
ec - J. A. Biddison, Esquire l G. F. Trowbrid 8e, Esquire. '
Mr. E. L. Conner, Jr. (!'RC) i Mr. Glenn Walton, NRC (F.ing of Prussia) !
i bec - Messrs. R. H. Kent /C. C. Lavrence, III/F. Fatnaik
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R. F. Ash / File I T. L. Sydnor - l R. M. Douglass j L. B. Russell i J. B. Bullock R. C. L. Olson
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