ML20248E852
| ML20248E852 | |
| Person / Time | |
|---|---|
| Site: | McGuire, Mcguire  |
| Issue date: | 10/02/1989 |
| From: | Tim Reed Office of Nuclear Reactor Regulation |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 8910060068 | |
| Download: ML20248E852 (25) | |
Text
- ____
4 T
[
^
'o UNITED STATES
.F-NUCLEAR REGULATORY COMMISSION n
y, E
WASHINGTON, D. C. 20555 October 2, 1989 I
Docket Nos. 50-369, 50-370 LICENSEE: Duke Power Company 4 -
FACILITY: McGuire Nuclear Station, Units 1 and 2
SUBJECT:
MCGUIRE SITE VISIT AND MEETING ON STEEL CONTAINMENT CORROSION On September 7,1989, NRC staff (T. A. Reed, K. R. Wichman, C. P. Tan) visited the McGuire Nuclear Station to observe the corrosion on the Unit I steel containment vessel and to meet with Duke Power Company (DPC) staff concerning the resolution of the corrosion problem for both McGuire units.
Meeting participants are listed in Enclosure 1.
The slides presented by DPC are provided in Enclosure 2.
During the morning, NRC and DPC. staff entered the McGuire Unit 1 containment annulus region.
Corrosion was observed on the outside surface of the one-inch thick steel containment vessel at the containment vessel-concrete floor interface.
The current identified maximum corrosion depth is 0.125 inches.
In the afternoon, NRC and DPC staff met to discuss the current status of the containment corrosion problem and DPC's action plan to resolve this issue for the McGuire station. The issues discussed included the location of corrosion areas, accessibility of the steel vessel-concrete interface area, DPC's estimate of the. corrosion rate, DPC's determination of the minimum acceptable vessel wall thickness, and the DPC action plan for resolution of the corrosion problem.
The minimum required wall thickness is 0.65 inches and the projected corrosion rate is.016 to.020 inches per year.
At this rate, the estimated remaining vessel wall thickness projected to the next refueling outa unit (0.824 inches for Unit I and 0.848 inches for Unit 2)ge for each McGuire remains greater than the minimum required wall thickness determined from ASME code allowable stress intensities.
DPC has planned immediate, interim, and long term actions for resolution of the
[
corrosion problem, which are identified in Enclosure 2 (last 3 pages).
The present plans are somewhat tentative as they are subject to continuing engineering review and management approval.
l l
9 l
8910060068 8?1002
}
PDR ADOCK 05000369 P
FDC L
(
s.
kE' Duke Power Company
_p_
Based upon the current DPC technical approach and identified actions to assess and resolve the corrosion problem for the McGuire station, the staff concludes
.that the minimum vessel wall thickness will not be violated and that ASME code allowable stress units' will not be exceeded.
Timothy A. Reed, Project Manager Project Directorate II-3 Division of. Reactor Projects I/II
Enclosures:
As stated cc w/ enclosures:
See next page i
i
r Duke Power Company McGuire Nuclear Station cc:
Mr. A.V. Carr, Esq.
Dr. John M. Barry Duke Power Company Department of Environmental Health P. O. Box 33189 Mecklenburg County 422 South Church Street 1200 Blythe Boulevard Charlotte, North Carolina 28242 Charlotte, North Carolina 28203
' County Manager of Mecklenburg County Mr. Dayne H. Brown, Chief 720 East Fourth Street Radiation Protection Branch Charlotte, North Carolina 28202 Division of Facility Services Department of Human Resources 701 Barbour Drive Mr. J. S. Warren Raleigh, North Carolina 27603-2008 Duke Power Company Nuclear Production Department Mr. Alan R. Herdt, Chief P. O. Box 33189 Project Branch #3 Charlotte, North Carolina 28242 U.S. Nuclear Regulatory Connission 101 Marietta Street, NW, Suite 2900 J. Michael McGarry, III, Esq.
Atlanta, Georgia 30323 Bishop, Cook, Purcell and Reynolds 1400 L Street, N.W.-
Ms. Karen E. Long Washington, D.
C.-
20005 Assistant Attorney General N. C. Department of Justice Senior Resident Inspector P.O. Box 629 c/o U.S. Nuclear Regulatory Commission Raleigh, North Carolina 27602 Route 4, Box 529 Hunterville, North Carolina 28078
'Mr. H. B. Tucker, Vice President Nuclear Production Department Regional Administrator, Region II Duke Power Company U.S. Nuclear Regulatory Commission 422 South Church Street 101 Marietta Street, N.W., Suite 2900 Charlotte, North Carolina 28242 Atlanta, Georgia 30323 l'
Ms. S. S. Kilborn Area Manager, Mid-South Area FSSD Projects Westinghouse Electric Corporation MNC West Tower - Bay 239 P. O. Box 355 Pittsburgh, Pennsylvania 15230 l
l l
l l'
\\
v.
n.
2....
^
McGuire Nuclear Station Containment Corrosion Meeting 7 Septenber 1989 NAME ORGANIZATION PHONE
.D. E. DeMart DPC Design Eng.
(704) 373-4665 J. M. McConaghy DPC Design Eng.
(704) 373-7204 J. M. Kelly' DPC Design Eng.
(704)373-4215
'R. B. Hofmann DPC MNS MSRG (704) 875-4101 A. S. Daughtridge DPC Design Eng. Med (704) 373-7140 J. R. Hendricks DPC Design Eng. Sup (704)373-8442 G. J. Holbrooks DPC MNS MES MECH (704) E 75-4558 R. D. Broome DPC MNS Proj.Sycs.Mgr.
(704) 875-4242 D. J. Bumgardner DPC MNS OPS.
(704)875-4256 P. W. Roberson DPC NNS Perf.
(704)875-4587 R. O. Sharpe DPC MNS Compliance (704)875-4447 D. V. Ethington DPC MNS Compliance (704) 875-4474 T. A. Cooper NRC-Resident Insp.
(704)875-1681 T. A. Reed NRC/NRR/PDII-3 (301) 492-3474 K. Wichman NRC/NRR/EMCB (301) 492-0908 C. P. Tan NRC/NRR/ESGB (301) 492-0829 l
I
.g :
lL Enclosure ~21
~ '
a
.., ;~
- i
.i
- Meeting With.NRC j
Thursday, September 7,1939..
.McGuire Containment Corrosion Problem t
AGENDA Sequence of Events
-a Inspection Findings i
~*
Planned Actions I
Questions i
i l
l h
1 l
1 1
i i
. - =.
n.-..
_l-.-
w 4
4 SEQUENCE OF EVENTS Date Activity / Comments July 12-13 Performed Unit 2 EOC-5 ILRT Sructural Inspection.
1.
Discovered boric acid deposits on first horizontal ring stiffener.
2.
Identified ponding water on-the concrete annulus floor (Elev. 725'+00").between Azimuths 240* and 253*.
Area inaccessible.
Need for further inspection identified.
August 3 Inspection team consisting of structural and coatings personnel performed further investigation of area at Elevation 725'+00" between Azimuths 240*-253*.
1.
Discovered boric acid deposits on the steel containment vessel (SCV) and at the SCV-concrete floor interface.
2.
SCV and concrete floor coating failure was evident.
3.
Visual evidence of SCV corrosion.
4.
Continued visual inspection at Elevation 725'+00" entire 360*.
Due to HVAC duct, the SCV-concrete interface was only accessible between Azimuths 164*-253' and 270*-330*.
k V-i August 4 Developed plan of. action for additional investigations.
1.
Remove existing coating 9" high on SCV by blasting.
2.
Determine acceptable coating for immersed conditions.
3.
Determine acceptable sealant.
4.
Investigate HVAC duct removal'for further i
inspection of SCV.
August 7-10 Removed existing coating 9" high on SCV of the accessible areas.
August 11 Determined HVAC duct was not designed to be removable.
Removal of duct would require installation of new duct.
Duct material was unavailable.
Estimated the removal and reinstallation to be eight weeks.
Optimal resolution is to relocate duct.
Delay until next outage unless inspection dictates otherwise.
August 12 Performed ultrasonic examination of previously identified significant isolated pits. UT was determined to be inadequate due to pit size, location, and orientation (transducer too large).
Continued existing coating removal on SCV and concrete floor.
August 14 Developed SCV pit inspection methodology.
August 15 Meeting with station QA and DE personnel to l
discuss inspection implementation.
It was determined that DE personnel would perform the SCV pit inspection and documentation.
The pit measurement techniques and procedures were observed by QA personnel and approved.
Initiated the following Problem Investigation Reports (PIR):
1.
PIR 2-M89-0203:
Numerous coating failures on the SCV exterior face near Elev. 725'+00".
Corrosion of up to 0.10" observed.
2.
PIR 2-M89-0204:
The annulus SCV-concrete.
interface was not sealed.
3.
PIR 2-M89-0205:
Coating failures and/or lack of coating observed on penetrations M276, M302, and M341.
August 16-17 Performed pit measurements.
August 17 Informed DE Management of current inspection findings.
Discussed continued course of action.
1.
Continue pit measurements.
2.
Remove concrete in worst case location of SCV corrosion (AZ 240*-243*).
3.
Remove insulation panel from SCV in the pipe chase to inspect the SCV interior.
August 18 Removed concrete between Azimuths 240' and 243*.
Thoroughly documented pitting in this area.
Removed two insulation panels from.the SCV in the pipe chase to' inspect the SCV interior.
August 19 Completed SCV pitting measurements.
l
. Documented-boric acid deposit locations, instrumentation line locations, deleted l
instrumentation line locations, ring stiffener hole locations.
Inspected SCV interior face at removed insulation panel locations.
l August 21 Discussed inspection findings with DE Management.
1 August 22-23
' Determined corrective actions.
Initiated tabulation of inspection findings.
Reviewed SCV Stress Report and ASME requirements for minimum j
wall calculations.
1 l
1 August 24 Discussion of inspection findings and corrective actions with DE and Station Management personnel.
Degradation of the SCV was determined to be reportable to the NRC.
Station received verbal operability notification for Units 1 and 2 from DE.
Station received verbal approval from DE to proceed with Unit 2 ILRT.
August 29-30 Preliminary inspection of the Unit 1 SCV exterior surface was performed.
l 1
_a
h?? a, p".7. -..
1: '.c; an,
p--
c-,-
l
+
MCGUIRE NUCLEAR STATION UNITS 1-& 2 Steel. Containment Vessel Inspection History Summary UNIT 1 Date Activity Comments July 13, 1979_
Pre-operation No ponding water or coating-failures observed.
Feb. 21-25, 1983 ILRT Structural At various* locations water Visual Inspection was ponding on horizontal stiffeners.
No corrosion of the SCV surfaces was observed.
Aug.'14-17, 1986 ILRT Structural No ponding water or Visual Inspection coatings failures noted.
UNIT 2 Date Activity Comments Aug. 26-27, 1982 Pre-operation No ponding water or-coating failures observed.
May 23-26, 1986 ILRT Structural Boric acid deposits were
~
Visual Inspection identified at AZ 195* Elev
~
725'+00" (concrete floor and horizontal stiffener).
Ponding water observed on horizontal stiffeners between AZ 220* and 235*
at Elev. 806'+0".
No corrosion on the SCV surfaces were noted.
July 12-13, 1989 ILRT Structural Ponding water and coating Visual Inspection failures noted. Additional inspections initiated.
v
.-.N N
e b L&l 2m C3 WQ
~
$L aC U
$E
- 5 s
5 as Em g
.A
>=
W to E4 tnD~'
.... :.%%* *'.*f. r..m.
6,gg)l, VPPP *#i'##%l)g,g,,,
5
...rr'*:
+ 9 9 %...
.. 4*#'* -
'*P%*..
. 99%*
'9%*..
99q _
,pp:
osos.
pp:
~ *P%.
'o#%.
.4*?'
9+.
..*T'
'o9
.?%
a:p.
pqo:
a:p.
pp:
g
.%*i 9m er:
.?'
b.
??'
.f'
?%*
~
f%
- 74 o
HpHp-co
- %9%
o ----
tfJ t;9%
>:p:
pq
.?'
P%
.P'
. P-P%.
.?%
(
- 9'.
- f
- .* f
?%
_p:
- o: _
_ pp:
.0%.
o p.,
pp:
sop.
P'..
.%*f o
..*P nn
...%*P -
to?.
- .9P'
...?#
'o#'..
..*f P
'*# P..
...f;*T'
'o # %*.*....
......*# P
~ 'o# %*.*.*f P.* :.*f#%*ff ? * '
- or.o.p:p o:pqoco: -
e" S
N
c.;
N w
+
e 3$
u.
8 r
....x.u*+ ep 6.
L* R4*4 Nh%6p;.,.
_,,p.j y?$$$PPP
'*'*#;*;.6.;_.,_
.. :.6p. 4*p:*:
- 0:
- op% op:N
..?pp-
,%.' I d,'
- ' ),*..
.pp:
.4*%* -
- .*9:
..*?:
~*%*L.
o%o
'pk _
.p:
f4*:
99 t
6.# r r%.
op.
'p:)
o.
p?
p
' f*
- $.'*e.
d.p, k.
?%*%<
- i..o.
o-
.-~
.o.
?!
o i:p. c
%97 o:
'g?
.p:
.p
%*6 6p.
i,*..
j%d
.p; P'
p:
- P.
6p-
?.
.k*%
9?
.* p :
6*#
d
. A..%*%*
p%o, P
pp,.
'*PL.
,):,6.?., "
. :.*p: '
n
. 4%*p:
- pp7...
....%*p
' N?#'
' '*%*%*;*%*;oso p p. opp.;6.y.y.,'o
- o p pp.p.co
?
)
Sa
)S 0
E 9
N L
I N
<ib O
. ? ? ? ? ?o b 67??T??
I
. ? ?o8ddd8a.d6&Ud8'?'?
T
??* ??P 7??????
A
.? ? g.8d' s~
- ' ~
~
8 T
d d 6' d8.Sd'? ?
?
??
d 8 8'? '?
N
.???
??
s8$~
688~
E
???
???
M o d8' ~
6 8 d*'?
.f*
?
U
.dd~
- d. d '?
??
?
R
.Sd ~
68~
?*
- ?
T
. d 8*
~
N
. S 8*'
6 8 "?
?
S
?
6 d* ~
?
?
I 6 6* ~
6.d.-
?
?
D
. ?o d~
6_'
?
E
.d'
- 4. b
?
?
. d* ~
d*.'?
L 6~
- 6. d'
?
?
E 8~
d~
?
D
??
- .8' 68~
o?
(
T 5
.d' B~
?*
??
1
- o. d ~
- 6. d
?
?
d6
.d~
?*
?*
. '. ~
d ~*
?
.d' 6.$
?
?
- o. 8 '
- o. 8 -
?
?
o8
.d-
?*
b5 d 2*
- v. d
?*
.8
?
.?
$A
,. d 2 o
N**
?
?*
5 R*
82
?
?
o*A
. d*
6a
- v. d ~
??
?
o*.6
- v. d -
?.
- o. 6
- o. d -
?
.s'
'o 8 d'
.d~
?
~
?'
?*
?o ~
~ ~
?
- o. 6 ~
?o d '
?
?
d '~
.?'
f*
?*
.&~
o.8
?
?
.d
.d8 f*
?*
- o. 'o os~
f?
d~
_ d ~*
- ?
?
- o. d *
.,d*^^
?
- d. s '
?.o-
?
d6
.d-
?
??
d~
.dd
??
?*
od~
.d8~
??
?*
d6 dd '
??*
.??*
d d '?
odd
?f
.??
- o. d'?
S8~
?
.???
6 6 d '?
. ? odd ~
??
?*
d.d d'o dd* ~
d 6* d~
???
?
.?
o6;? "6
.?'+
?*
?-
??
od~.dS6 o oddd'ddd8 P?
???f
??????+
d d d*. d* 76dd~ '
0 6
7 0
8 2
8 2
3 2
52 l'
s o; 0-g E
g 3
gA.
E p:.
j 8
....r.9 %'? R%'.9....
_,,pppro:.%*fff%* P%*P%*%*%*f.o.%.p:p..
....ff p.;,,,
...Pf:0:
.o p ps...
..pp:o-
- opq _
. *%*f'
- f;*..
..*P-
- P%.
'*P:..
'*f %.
.?%.
. 9?-
'P-
.P' op
.9%
.??-
o?-
.P'
'?%.
.*f op.
.p.,
p oy
-p:
pp
}
.9%
.f'
'*?
l
- f Rf-pp qp:
%*1
,;*1
??%
- PV o
- L'
- Z; 8
ti'V i'1
%*?
.* f 9%*
.*f f%
.t..
io%
.P'
(
- f i'i.
.i'i
- *P.
..*P'
'*f -
.*f'
.f'
- ?
f%*
%*f..
..*f'
'*f%.
. ??'
opp.
.. o.,
o:
' *P %*...
.. %*?* '
y a
' N*
'&y.y.y:;oppp pppp.;6:,6.y$ ?#
- o:s s f p:p:s:s: -
$g W
J
>9g C
~
$u W
N J
Q u
N
gmE m
A ETRG EON R TI T
CC D L
N NAI E
OEU M
)S N
E L
IA E N
RT S I
L E NS N
TOE O
SCV T
A I
)S A
E E
T R
N N
A
~
I L
E S
M U
N U
L i***
6*$*
O R
U S ;;
?
oE* * &f%??h 0
I T
T N
s*
?*
4fE[ j A
S N
?h?
j
&Y T
N A
y
??
l5a'd~
N I
$'?
E D
o&E*
aS M
E k
?
?,
U T
l5 '
, ) ?'
R E
g N*
6.%'*
L i
T f
6E[
E S
D y -
N
(
g4 I
g.
9 D
2
.**g--
4. ;
E k
?
T L
E
?
h L
o
$~
E
(
D f
?o3
?
.?
(
E 5
,6'
?*
j
,d* ~
g 1
g' g 3*
y 3
.g'
.y' o.9
- o3 6<-
f
?
{
0
_ S.-
?
4* ~.
o3 t.
o,g.
a
- 3. '
3 3'?
3' 7*
~
7,s?
- p~
s'*
[(
)3 o.a?a*
);%
rp.
$~
.s *
.S 5
?sM o E*
?'
g$ ~
0 p$
3 g'?
y 3
8[
j[
gS[
.6 j[
. 5*; -
I)f g$'
y?5
. ; S:
g N
6?f~ &
?
? ;;,
D O EI L g?r
)'*
9~
V T E 64 o&y 3
O A N L
? ? g'g;?
- 6g I* s [ g.
L
?
f?
M U A I6Ig6B' P
E S N
R N DO I
EI L V T E 9
O A N 0
3 L
6 7
2 M U A 8
0 P
2 8
2 EL 3
0 E S 5
3 4
2 T A R N E V 2
2 4
2 I
R O C M N E O R C
l
O o
Io 2
z 8
O E
5 7
.W o
m Q
o" Z
o vn e
c O
o O
S$$$U35$
0 S$$$U35$
e l
Te MCGUIRE UNIT 2 SCV CROSS-SECTION AZIMUTH 240 - 243 ANNULUS L
/
I I
I 4.0' I
I I
I 3.0' I
20-3 MILS 20-35 MILS--*
+
2.0' I
PIPE 40-45 MILS-*
+-
CHASE I
40-45 MILS r
i 123 MILS =
=
1 ELEV. 725' t
I 20,30 M I L S--* e'
~
PIPE CHASE'.
l
..[
-1.0" i
CONCRETE 1
. -Q l
ANNULUS l
CONCRETE 150
^
^
-2.0' i
100 e.2 1
50 I
MILS e
1.00' (1000 MILS)
FIGURE 6
. S.u UNIT 1 PRELIMINARY INSPECTION FINDINGS Similar Coating Failures as Unit 2 Similar Ponding of Water as Unit 2 I
1.
Azimuth 218' to 2536 More Extensive Boric Acid Deposits Than Unit 2.
~
'1.
Azimuth 121* to 198*
2.
. Azimuth 206* to 253*
3.
Azimuth 284*-to 330'
- Comparable Corrosion Depths as Unit 2 Pit Height Maximum Azimuth-Above Elev. 725 Pit Depth (deg)
(inches)
(mils) 216 0 to.5 103 218 0 to.5 60 221 0 to.5 55 228 0 to.5 73 245 0 to.5 82 316 0 to.5 125
'r
__m__-__ _ _ _ _ _ _ _ _ _.. _ _ _ _ _. _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ - _. _. _ _ _ _ _ _ _ _ _
[
Ecrm 01163 v
PROJECT ticGUIRE MUCLLC STATTP.J g j [y, CONTAIT'ENT "ESSEL ANALYS;S
.PAGE 2-3a ORIGINATEDBYpC u d fb DATE p.19.14 CHECKED BY Nd*bd DATE WM 3 W-99
~
(L g,/
EL 894+3~
qk[
+
j
.,Y t
/
e N6N.
t EL. 836 + 9 L
1 h 3/ THK.
i M
CC b
i I
I l
EL.737 5 4
Fl.
_ I THK, e
EL.723'+ 6 I' y _
H Cr ;g 14 T H'K-EL 694-4Y If FIGURE 2-1 -THE PLATE THICKNESS CF CONTAINMENT VESSEL.
' Fcrm~0ll63
)
4 PROJECT McGUiRE NUCLEAR STATION ITEM DFEfGN CRITFRfA PAGE g l
ORIGINATED BY M]d D ATE-fM>9 CHECKED BY b
DATE9fid?9 s
TABLE 1-2 i
FSAR TABLE 3.8.2-2 Containment Materials I
Material Location Material Specification j
Base Liners SA 516, Grade 60 Base Liner Embedments SA 516, Grade 60 and/or 1
' Knuckle Plate SA 516, Grade 60 I
Shell and Dome Plate SA 516, Grade 60 e
Penetrations (Piping and Electrical)
SA 333, Grade B and/or SA 516, Grade 60 Personnel Locks SA 516, Grade 60 and/or Grade 70 Stiffeners SA 516, Grade 60 Equipment Hatch SA 516, Grade 60 and/or Grade 70 Anchor Bolts SA 320-L43 1
Anchor Bolt Anchor Plates SA 516, Grade 60 l
j
. l 15.
i l
1 4
)
- -__ __ - - _ -____ _ _ D
k Eda 01163 1
t PROJECT' McGUIRE NUCLEAR STATION ITEM PAGE l-13 bkg D ATE M U ORIGINATED BY Ad/Id DATE ~!i.-/4 9 CHECKED BY Table 1-1 FSAR Table 3.8.2-1 Containment Vessel Loadino Combination and Code Requirements Loadino Combination Code Reference DL + CL ASME - Normal Condition DL + OL + DBA ASME - Normal Condition DL + OL + OBE ASME - Normal Condition DL + OL + OBE + P' ASME - Normal Condition DL + OL + SSE ASME - Emergency Condition DL + OL + SSE + DBA ASME - Emergency Condition DL + OL + SSE + P' ASME - Emergency Condition ASME = ASME Boller and Pressure Vessel Code, Section lit, Subsection B, 1968, including all addenda through Summer of 1970.
DL
= Own weight of the Containment Vessel and all the permanent at-tachments to the Containment.
CL
= Construction Loads.
DBA = Design Basis Accident which includes temperature and pressure l
effects.
03E = Operating Basis Earthquake, 8 percent G.
SSE = Safe Shutdown Earthquake, 15 percent G.
I OL
= Normal Operating Loads of the Containment Vessel, including Live Loads, thermal loads and operating pipe reactions.
P'
= External pressure due to the internal vacuum created by accidental trip of the Containment Spray System.
Stress limits of the Containment Vessel are as prescribed in Figure N-414 of the ASME, Section 111, Nuclear Vessels, 1968, including all the addenda up to the Summer of 1970.
Buckling is considered in all loading combi-nations.
l l
4
~
a e
i d.
~
MINIMUM WALL DETERMINATION f
Review all load combinations for actual stresses at base.
Back-calculate required thicknesses based on ASME code allowable stress intensities.
Controlling. combination equivalent " Level B" (OBE + LOCA) excluding-thermal effects.
i Minimum wall established at 0.65 inches.
i
- 1 PROJECTED CORROSION RATES
- 16 to 20 mils per year
- Based on assumed uniform rate since Initial Fuel Load for measured data.
ESTIMATED REMAINING SHELL THICKNESS AT BASE Averaae
' Worst Case Unit 1 0.852 inches 0.824 inches Unit 2 0.872 inches 0.848 inches Values shown include projection to next outage.
I I
r
{.. f,
i ACTUAL MATERIAL PROPERTIES OF BASE SHELL COURSE Yield Tensile Min.
Mean Min.
Mean Unit 1 42.8 45.4 63.0 65.9
. Unit 2 43.5 46.6 63.7 67.0 Code 32.0 60.0 CONTRIBUTING FACTORS TO CORROSION Ponding Water Drain Operation Boric Acid Deposits Coating Failures Lack of Sealant
O.5 IMMEDIATE ACTION 1.
Properly coat SCV interior face exposed areas where insulation panels have been removed.
Action:
Implementation per MEVN-2005.
Coat exposed steel with Service Level I Coating System 106-I and reinstall stainless steel cover 2.
Recoat concrete. floor in accordance with Coating Specification 305.
Recoat at least the first nine inches of the steel containment vessel in accordance with Coating Specification 303.
Seal joint between containment vessel (including vertical stiffeners) and concrete floor with Sealant Specification 7004.
Action:
Implementation per MEVN-1951
. Clarification:
Recoat accessible concrete floor and entire containment vessel between Azimuth 270* - 330' and 164' - 253*.
3.
Repair concrete at - 240' - 243*.
4.
Conduct preliminary inspection of the Unit 1 containment vessel pitting in the annulus.
Action:
Completed preliminary inspection of the SCV exterior face August 29-30, 1989.
5.
Take immediate temporary measures to contain water / acid leaks.
g-f;
, g,.
_, ~ Y '
l.
r.
~
' Du ke - Power Company I Based upon the current DPC technical approach and identified actions to assess t-
.and resolve the corrosion problem for the McGuire station, the staff cencludes
'that the minimum vessel wall thickness will not be violated and that ASME code h-allowable' stress units will not be exceeded.
/s/
4 Timottty A. Reed, Project Manager Project Directorate 11-3 Division of Reactor Projects I/II-
Enclosures:
As stated cc w/ enclosures:
See next page Distribution Facility: McGuire Units 1 and 2 (Docket (Fjle5@'
R. Ingram 14 H.25 NRC PDR T. Reed 14.H-25 Local PDR~
OGC 15.B-18 PDII-3 Reading E. Jordan MNBB-3302 T. Murley 12-G-18 B. Grimes 9-A-2 J. Sniezek 12-G-18 HRC Participants D. Matthews 14-H-25' ACRS (10)
P-315 D. Hood 14-H-25 B. Borchardt l.17-D-19 Anh 0FC :PDll-3
- PDll-3
- P
- PDll-3
- PDll-3 I y.
..... :....g...... :.... r
- T Rk h mar =~ :DHood dJ//.DMatthews
. NAME :RIngram
___.........:..._____.. n.__......_:....__......:.........
_..........:f $ 89
- f/,y/89
>:Q/9y89 DATE : $/$/89
- fMF/89 7
OFFICI AL RECDRD COPY acument Name: MEETING
SUMMARY
9/21